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 March 31, 2010

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

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

A total of 4,217,596 shares of Common Stock were outstanding at May 7, 2010.

PART 1 – FINANCIAL INFORMATION

Item 1. Financial Statements

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

	Three Months Ended
	March 31,
	2010			2009
REVENUES:
Marketing	$	518,090		$	327,112
Transportation		13,111			10,943
Oil and gas		2,584			2,086
		533,785			340,141
COSTS AND EXPENSES:
Marketing		513,762			320,958
Transportation		11,136			10,207
Oil and gas		1,204			1,435
General and administrative		2,264			2,310
Depreciation, depletion and amortization		2,844			2,431
		531,210			337,341

Operating earnings		2,575			2,800

Other income (expense):
Interest income		11			32
Interest expense		(31	)		(6	)

Earnings before income tax		2,555			2,826

Income tax (provision) benefit		(761	)		(956	)

Net earnings	$	1,794		$	1,870

EARNINGS PER SHARE:
Basic and diluted net earnings per common share	$	.43		$	.44

DIVIDENDS PER COMMON SHARE	$	-		$	-

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

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

	March 31,			December 31,
	2010			2009
ASSETS
Current assets:
Cash and cash equivalents	$	23,380		$	16,806
Accounts receivable, net of allowance for doubtful
accounts of $1,310 and $1,681, respectively		170,234			155,941
Inventories		16,498			15,260
Fair value contracts		2,865			1,581
Income tax receivable		1,547			2,171
Prepayments		6,124			10,804

Total current assets		220,648			202,563

Property and Equipment		136,476			132,660
Less – Accumulated depreciation, depletion and amortization		(93,033	)		(90,355	)
		43,443			42,305
Other Assets
Deferred income tax asset		1,496			1,290
Cash deposits and other		3,322			3,243
	$	268,909		$	249,401
LIABILITIES AND SHAREHOLDERS’ EQUITY

Current Liabilities:
Accounts payable	$	173,853		$	158,176
Accounts payable – related party		85			75
Fair value contracts		2,601			1,331
Accrued and other liabilities		4,496			3,872
Current deferred income taxes		871			737
Total current liabilities		181,906			164,191

Other Liabilities:
Asset retirement obligations		1,320			1,315
Other liabilities		88			94
		183,314			165,600

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		73,480			71,686
Total shareholders’ equity		85,595			83,801
	$	268,909		$	249,401

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

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

	Three Months Ended
	March 31,
	2010			2009
CASH PROVIDED BY OPERATIONS:
Net earnings	$	1,794		$	1,870
Adjustments to reconcile net earnings to net cash
from operating activities -
Depreciation, depletion and amortization		2,844			2,431
Property sale (gains) losses		(73	)		(55	)
Dry hole costs incurred		21			224
Impairment of oil and gas properties		407			124
Provision for doubtful accounts		7			46
Deferred income taxes		(71	)		787
Net change in fair value contracts		(14	)		(142	)
Other, net		(13	)		479
Decrease (increase) in accounts receivable		(14,300	)		8,107
Decrease (increase) in inventories		(1,238	)		3,099
Decrease (increase) in income tax receivable		624			71
Decrease (increase) in prepayments		4,680			(5,585	)
Increase (decrease) in accounts payable		15,682			(1,836	)
Increase (decrease) in accrued liabilities		22			(636	)

Net cash provided by operating activities		10,372			8,984

INVESTING ACTIVITIES:
Property and equipment additions		(3,807	)		(4,907	)
Insurance and state collateral (deposits) refunds		(68	)		(38	)
Proceeds from property sales		77			64

Net cash (used in) investing activities		(3,798	)		(4,881	)

Increase in cash and cash equivalents		6,574			4,103

Cash and cash equivalents at beginning of period		16,806			18,208

Cash and cash equivalents at end of period	$	23,380		$	22,311

The accompanying notes are an integral part of these financial statements

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED

CONSOLIDATED FINANCIAL STATEMENTS

Note 1 - Basis of Presentation

The accompanying condensed consolidated financial statements are unaudited but, in the opinion of the Company's management, include all adjustments (consisting of normal recurring accruals) necessary for the fair presentation of its financial position at March 31, 2010, its results of operations for the three months ended March 31, 2010 and 2009 and its cash flows for the three months ended March 31, 2010 and 2009. 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 March 31, 2010 has been evaluated through the date of issuance of these financial statements.

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.

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 may invest 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 investments in municipal bonds at March 31, 2010 or December 31, 2009. Cash and cash equivalents are maintained with major financial institutions and such deposits may exceed the amount of federally backed insurance provided. While the Company regularly monitors the financial stability of such institutions, cash and cash equivalents ultimately remain at risk subject to the financially viability of such institutions.

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):

	March 31,		December 31,
	2010		2009

Crude oil	$	15,011	$	14,053
Petroleum products		1,487		1,207

	$	16,498	$	15,260

Prepayments

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

	March 31,		December 31,
	2010		2009

Cash collateral deposits for commodity purchases	$	3,322	$	7,670
Insurance premiums		1,519		2,478
Natural gas pipeline imbalances		789		89
Rents, license and other		494		567

	$	6,124	$	10,804

Property and Equipment

Expenditures for major renewals and betterments are capitalized, and expenditures for maintenance and repairs are expensed as incurred. Interest costs incurred in connection with major capital expenditures are capitalized and amortized over the lives of the related assets. When properties are retired or sold, the related cost and accumulated depreciation, depletion and amortization ("DD&A") is removed from the accounts and any gain or loss is reflected in earnings.

Oil and gas exploration and development expenditures are accounted for in accordance with the successful efforts method of accounting. Direct costs of acquiring developed or undeveloped leasehold acreage, including lease bonus, brokerage and other fees, are capitalized. Exploratory drilling costs are initially capitalized until the properties are evaluated and determined to be either productive or nonproductive. Such evaluations are made on a quarterly basis. If an exploratory well is determined to be nonproductive, the costs of drilling the well are charged to expense. Costs incurred to drill and complete development wells, including dry holes, are capitalized. As of March 31, 2010, the Company had no unevaluated or suspended exploratory drilling costs except for a single well that was spud in December 2008 and reached total depth in February 2009. The operator of the well has been content to allow the well to remain idle pending installation of a gas lift system in order to establish production. The Company’s total capitalized cost for this well is $328,000. Management believes the cost of the well will not be fully recovered through future production. Therefore a $164,000 impairment valuation was applied to these property costs.

Depreciation, depletion and amortization of the cost of proved oil and gas properties is calculated using the unit-of-production method. The reserve base used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. For lease and well equipment, development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. All other property and equipment is depreciated using the straight-line method over the estimated average useful lives of three to twenty years.

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 that uses market based inputs. 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 three-month periods ended March 31, 2010 and 2009 there were $5,700 and zero impairment provisions on producing oil and gas properties, 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 $401,000 and $124,000 were recorded for the three-month periods ended March 31, 2010 and 2009, respectively. 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.

Cash deposits and other assets

The Company has established certain deposits to support participation in its liability insurance program and remittance of state crude oil severance taxes and other state collateral deposits. Components of cash deposits and other assets are as follows (in thousands):

	March 31,		December 31,
	2010		2009
Insurance collateral deposits	$	2,648	$	2,648
State collateral deposits		203		271
Materials and supplies		471		324
	$	3,322	$	3,243

Revenue Recognition

Commodity purchase and sale contracts utilized by the Company’s marketing businesses qualify as derivative instruments. All natural gas and 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 elects the normal purchases and sales exception methodology for such activity. For normal purchase and sale activities, the Company’s customers are invoiced monthly based upon contractually agreed upon terms with revenue 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.

Letter of credit facility

The Company maintains a Credit and Security Agreement with Wells Fargo Bank to provide a $40 million letter of credit facility. 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 $33.9 million as of March 31, 2010. 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 $31,000 and $6,000 during the three-month periods ended March 31, 2010 and 2009, respectively. Income taxes paid during these same periods totaled $56,000 and $24,000, respectively. Non-cash investing activities for property and equipment were $1,047,000 and $530,000 as of March 31, 2010 and 2009, respectively and $440,000 and $561,000 as of December 31, 2009 and 2008, respectively. 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 2010 and 2009. 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 oil and gas reserve volumes that form the foundation for (1) calculating depreciation, depletion and amortization and (2) deriving cash flow estimates to assess impairment triggers or estimated values associated with oil and gas property, revenue accruals, 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 March 31, 2010 as follows (in thousands):

	Balance Sheet Location and Amount
	Current			Other		Current			Other
	Assets			Assets		Liabilities			Liabilities
Asset Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation	$	3,577		$	-	$	-		$	-

Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-			-		3,313			-

Less Counterparty Offsets		(712	)		-		(712	)		-

As Reported Fair Value Contracts	$	2,865		$	-	$	2,601		$	-

Forward month commodity contracts (derivatives) are reflected in the accompanying Consolidated Balance Sheet as of December 31, 2009 as follows (in thousands):

	Balance Sheet Location and Amount
	Current			Other		Current			Other
	Assets			Assets		Liabilities			Liabilities
Asset Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation	$	2,035		$	-	$	-		$	-

Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-			-		1,785			-

Less Counterparty Offsets		(454	)		-		(454	)		-

As Reported Fair Value Contracts	$	1,581		$	-	$	1,331		$	-

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 March 31, 2010 and December 31, 2009, the Company was 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 three months ended March 31, 2010 and 2009 as follows (in thousands):

	Earnings (Loss)
	Three Months Ended
	March 31,
Location	2010	2009

Revenues – marketing	$ 14	$ 142

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. Source data for Level 2 inputs include information provided by the New York Mercantile Exchange “NYMEX”, Intercontinental Exchange “ICE”, published price data and indexes, third party price survey data and broker provided forward price statistics.

Level 3 – Unobservable market data inputs for assets or liabilities.

As of March 31, 2010, 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 – Forward Hydrocarbon
Commodity Contracts
- Current assets	$	163	$	2,702		$	-	$	2,865
- Current liabilities		-		(2,601	)		-		(2,601	)
Net Value	$	163	$	101		$	-	$	264

As of December 31, 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 – Forward Hydrocarbon Commodity Contracts
- Current assets	$	224	$	1,357		$	-	$	1,581
- Current liabilities		-		(1,331	)		-		(1,331	)
Net Value	$	224	$	26		$	-	$	250

When determining fair value measurements, the Company makes credit valuation adjustments to reflect both its own nonperformance risk and its counterparty’s nonperformance risk. When adjusting the fair value of derivative contracts for the effect of nonperformance risk, the impact of netting and any applicable credit enhancements, such as collateral postings, thresholds, and guarantees are considered. Credit valuation adjustments utilize Level 3 inputs, such as credit scores to evaluate the likelihood of default by the Company or its counterparties. As of March 31, 2010 and December 31, 2009, credit valuation adjustments were not significant to the overall valuation of the Company’s fair value contracts. As a result, applicable fair value assets and liabilities in their entirety are classified in Level 2 of the fair value hierarchy.

New Accounting Pronouncements

As of January 1, 2010, the Company adopted Financial Accounting Standards Board issued Accounting Standards Codification Update No. 2010-06 – Fair Value Measurements and Disclosures (Topic 820): Improving Disclosures about Fair Value Measurements. The update requires enhanced disclosure of transfers between Levels 1, 2, and 3 of the fair value hierarchy, level of disaggregation of derivative contracts for fair value measurement disclosures, and disclosures about fair value measurement inputs and valuation techniques. The Company has included these enhanced disclosures, where applicable, in its first quarter filing on Form 10-Q.

Management believes the impact of other recently issued standards and updates, which are not yet effective, will not have a material impact on the Company’s consolidated financial position, results of operations or cash flows upon adoption.

Note 3 – Segment Reporting

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. 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):

- Three Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended March 31, 2010
Marketing
- Crude Oil	$	487,579	$	3,043		$	498	$	1,427
- Natural gas		2,686		605			41		-
- Refined products		27,825		14			127		76
Marketing Total		518,090		3,662			666		1,503
Transportation		13,111		861			1,114		16
Oil and gas		2,584		316			1,064		2,288
	$	533,785	$	4,839		$	2,844	$	3,807
Period Ended March 31, 2009
Marketing
- Crude Oil	$	300,453	$	3,831		$	529	$	658
- Natural gas		3,907		1,352			41		-
- Refined products		22,752		265			136		129
Marketing Total		327,112		5,448			706		787
Transportation		10,943		(178	)		914		1,144
Oil and gas		2,086		(160	)		811		2,976
	$	340,141	$	5,110		$	2,431	$	4,907

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

	Three Months Ended March 31,
	2010			2009
Segment operating earnings (loss)	$	4,839		$	5,110
- General and administrative expenses		(2,264	)		(2,310	)
Operating earnings		2,575			2,800
- Interest income		11			32
- Interest expense		(31	)		(6	)
Earnings before income taxes	$	2,555		$	2,826

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

	March 31,		December 31,
	2010		2009
Marketing
- Crude oil	$	157,818	$	130,840
- Natural gas		26,492		40,715
- Refined products		11,083		10,133
Marketing Total		195,393		181,688
Transportation		16,059		16,078
Oil and gas		27,309		26,050
Other		30,148		25,585
	$	268,909	$	249,401

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 three months of 2010 and 2009, the Company’s investment commitments totaled approximately $2.3 million and $3.3 million, respectively, in those oil and gas projects where a related party was also participating in such investments. As of March 31, 2010 and December 31, 2009, the Company owed a combined net total of $85,000 and $75,000, 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 $39,000 and $34,000 in the three-month periods ended March 31, 2010 and 2009, 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 administrative services. For the three-month period ended March 31, 2010 and 2009, the affiliated entities charged the Company $12,000 and $29,000, respectively, of expense reimbursement and the Company charged the affiliates $29,000 and $40,000, respectively, for such expense reimbursements.

Note 5 - Commitments and Contingencies

Under certain of the Company’s automobile and workers compensation insurance policies, the Company can either receive a return of premium paid or be assessed for additional premiums up to pre-established limits. Additionally, under the policies in certain instances the risk of insured losses is shared with a group of similarly situated entities. Estimated loss accruals for potentially unknown losses are developed using actual loss histories and other relevant information. As of March 31, 2010, management has appropriately recognized estimated expenses and liabilities related to the program.

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

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

Results of Operations

Marketing

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

			Segment		Depreciation
			Operating		Depletion and
	Revenues		Earnings		Amortization
Period ended March 31, 2010

- Crude Oil	$	487,579	$	3,043	$	498
- Natural gas		2,686		605		41
- Refined Products		27,825		14		127
Total	$	518,090	$	3,662	$	666

Period ended March 31, 2009

- Crude oil	$	300,453	$	3,831	$	529
- Natural gas		3,907		1,352		41
- Refined products		22,752		265		136
Total	$	327,112	$	5,448	$	706

Supplemental volume and price information is as follows:

	Three Months Ended
	March 31,
	2010		2009

Field Level Purchase Volumes – Per day (1)
Crude oil – barrels		69,763		68,537
Natural gas – mmbtu’s		242,044		391,492

Average Purchase Price
Crude Oil – per barrel	$	76.38	$	38.24
Natural Gas – per mmbtu	$	5.02	$	4.36

_____________________________

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

Crude oil revenues were increased during the 2010 period because of higher average crude oil prices as shown in the table above. The direction of change in price was also increasing as the average acquisition cost of crude oil moved from the $74 per barrel level at the beginning of the year to the $81 per barrel level for March 2010. This event produced an inventory liquidation gain of $1,267,000 for the first three months of 2010. Comparatively, while overall crude oil prices were reduced in 2009, the direction of change in price was increasing from the $41 per barrel range in January to the $48 per barrel range in March 2009. This event produced a $1,325,000 inventory liquidation gain in the first quarter of 2009. As of March 31, 2010 the Company held 184,911 barrels of crude oil inventory at an average price of $81.18 per barrel. Absent inventory gains, per unit margins were slightly reduced in 2010, which in turn caused an overall reduction in operating earnings for the 2010 period.

Natural gas sales are reported net of underlying natural gas acquisition costs and thus reflect gross margins. As shown above, such margins were reduced in the current quarter as average field level purchase volumes were off 38 percent for the period. Volumes declined in 2010 because previously the Company’s suppliers had been curtailing drilling activity due to lower natural gas prices. In addition, development of the nation’s natural gas infrastructure including more diverse areas of production and expanded pipeline and storage capacity have served to reduce purchase opportunities and per unit margins.

While refined products revenues increased in 2010 due to crude oil driven price increases, segment operating earnings were at break-even levels. During the first quarter of 2010, motor fuel sales volumes totaled 12 million gallons versus 14 million gallons during the first quarter of 2009. This volume reduction was in large part due to the December 2009 expiration of the federally sponsored one dollar per gallon tax subsidy on biodiesel fuel sales. Reduced demand particularly as it relates to the construction industry continues to suppress volumes and margins.

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.

- Transportation

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

	Three Months Ended
	March 31,					Increase
	2010		2009			(Decrease)

Revenues	$	13,111	$	10,943			19.8	%

Operating earnings (loss)	$	861	$	(178	)		583.7	%

Depreciation	$	1,114	$	914			21.9.	%

Revenues and operating results improved for the transportation segment in 2010 due to increased customer demand. The Company’s customers predominately consist of the domestic petrochemical industry and demand for such products has recovered to some extent. As transportation revenues increase or decrease, operating earnings will typically increase or decrease at an accelerated rate. This trend exists because the fixed cost components of the Company’s operation do not vary with changes in revenues. As currently configured, operating earnings project at break-even levels when quarterly revenues average $11.5 million. Above that level, operating earnings will grow and below that level, losses result.

Transportation segment depreciation increased in 2010 as the Company began replacing older fully depreciated tractor units with new model year vehicles. An additional 50 replacement units at an estimated cost of $5.5 million is also planned for the third quarter of this year.

- Oil and Gas

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

	Three Months Ended
	March 31,
	2010		2009			Increase
Revenues	$	2,584	$	2,086			23.9	%

Operating earnings (loss)	$	316	$	(160	)		297.5	%

Depreciation and depletion	$	1,064	$	811			31.1	%

The revenue and earnings improvement for the oil and gas segment is attributable to crude oil and natural gas price increases, partially offset by reduced production volumes, as shown in the table below. Depreciation and depletion expense is increased in the current period because an increased level of capitalized costs is being amortized in the current period following active drilling operations in 2009 and 2010.

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

	Three Months Ended
	March 31,
	2010		2009
Crude Oil
Volume – barrels		13,220		14,262
Average price per barrel	$	76.76	$	39.62

Natural gas
Volume – mcf		292,139		329,751
Average price per mcf	$	5.37	$	4.61

Comparative exploration costs are summarized in the table below. As shown, prospect impairment expense was increased in 2010 as certain adverse drilling results lead to unfavorable capitalized costs valuations. Exploration cost components were as follows (in thousands):

	Three Months Ended
	March 31,
	2010		2009
Dry hole expense	$	21	$	224
Prospect impairments		401		124
Seismic and geological		18		185

Total	$	440	$	533

During the first three months of 2010, the Company participated in the drilling of 10 successful wells with one dry hole. Additionally, the Company has an interest in thirteen wells that were in process on March 31, 2010. Evaluation on the in-process wells is anticipated during the second quarter of 2010. Participation in the drilling of approximately 44 wells is planned for the remainder of 2010 on the Company’s prospect acreage in Texas, Arkansas, Kansas and Louisiana.

- Outlook

The marketing and transportation segments have been performing at expected levels and within the transportation business, the outlook is for continued improvement. Within the oil and gas segment for the first quarter of 2010, crude oil and natural gas volumes fell below expectation. Active drilling continues and production volume increases should result. Recently, crude oil and natural gas prices have been volatile. A decrease in prices would have an adverse input on future earnings. Conversely, stable or increasing prices would yield earnings growth for 2010.

Liquidity and Capital Resources

The Company’s liquidity primarily derives from net cash provided by operating activities and such amount was $10,372,000 and $8,984,000 for each of the three-month periods ended March 31, 2010 and 2009, respectively. As of March 31, 2010 and December 31, 2009, the Company had no bank debt or other forms of debenture obligations. Cash and cash equivalents totaled $23,380,000 as of March 31, 2010, and such balances are maintained in order to meet the timing of day-to-day cash needs. Working capital, the excess of current assets over current liabilities, totaled $38,742,000 as of March 31, 2010.

Capital expenditures during the first three months of 2010 included $1,519,000 for marketing and transportation equipment additions and $2,288,000 in property additions associated with oil and gas exploration and production activities. For 2010, the Company anticipates expending an additional approximate $13 million on oil and gas exploration projects to be funded from operating cash flow and available working capital. In addition, approximately $5.5 million will be expended for the transportation segment during the third quarter of 2010 toward the purchase of 50 trucks-tractors with funding for such purchase from available cash flow. The units will serve to replace a like number of older model units.

From time to time, the Company may make cash prepayments to certain suppliers of crude oil and natural gas for the Company’s marketing operations. Such prepayments totaled $3,322,000 as of March 31, 2010 and such amounts will be recouped and advanced from month to month 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 $2,710,000 as of March 31, 2010. 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 periods in this filing. The Company does not look to proceeds from property sales to fund its cash flow needs. Except for a total of $1.9 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.

Historically, the Company pays an annual dividend in the fourth quarter of each year. In December 2009, the Company paid a $.50 per common share or $2,109,000 dividend to its shareholders. 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, 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, 2009.

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, 2009.

Forward-Looking Statements –Safe Harbor Provisions

This quarterly report for the period ended March 31, 2010 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) Fair Value Contract 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, 2009, under “Item 1A Risk Factor” that could cause actual results to differ materially from those expressed in any forward-looking statement made by or on behalf of the Company.

Item 4. Disclosure Controls and Procedures

The Company maintains “disclosure controls and procedures” (as defined in Rule 13a-15(e) and 15d-15(e) under the Securities and Exchange Act of 1934, as amended (the “Exchange Act”), that are designed to ensure that information required to be disclosed in the reports that the Company files or submits under the Exchange Act are recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and is accumulated and communicated to management, including the Company’s Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely discussions regarding required disclosure. As of the end of the period covered by this quarterly report, an evaluation was carried out under the supervision and with the participation of the Company’s management, including the Company’s Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures. Based upon that evaluation, the Chief Executive Officer and the Chief Financial Officer concluded that the design and operation of these disclosure controls and procedures were effective as of March 31, 2010.

Changes in Internal Control over Financial Reporting.

There have not been any changes in the Company’s internal control over financial reporting during the fiscal quarter ended March 31, 2010 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, 2009.

Item 2.

- None

Item 3.

- None

Item 4.

- Removed and Reserved

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: May 13, 2010	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