Edgar Filing: ADAMS RESOURCES & ENERGY, INC.

form_10q.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 September 30, 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 o NO x

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 x

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 November 12, 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)

	Nine Months Ended						Three Months Ended
	September 30,						September 30,
	2010			2009			2010			2009
REVENUES:
Marketing	$	1,531,930		$	1,391,453		$	484,412		$	562,834
Transportation		43,372			33,701			15,288			11,471
Oil and gas		8,079			6,356			2,755			1,994
		1,583,381			1,431,510			502,455			576,299
COSTS AND EXPENSES:
Marketing		1,519,158			1,373,305			479,059			558,314
Transportation		34,917			29,171			12,072			9,216
Oil and gas operations		4,970			6,297			2,171			2,834
General and administrative		6,659			6,946			2,257			2,252
Depreciation, depletion and amortization		8,425			7,517			2,875			2,537
		1,574,129			1,423,236			498,434			575,153

Operating earnings		9,252			8,274			4,021			1,146

Other income (expense):
Interest income		110			138			80			82
Interest expense		(32	)		(23	)		(1	)		(15	)
Earnings before income tax		9,330			8,389			4,100			1,213

Income tax (provision)		(3,089	)		(3,146	)		(1,338	)		(574	)

Net earnings	$	6,241		$	5,243		$	2,762		$	639

EARNINGS PER SHARE:
Basic and diluted net earnings per common share	$	1.48		$	1.24		$	.66		$	.15


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

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

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

	September 30,			December 31,
	2010			2009
ASSETS

Current assets:
Cash and cash equivalents	$	30,303		$	16,806
Accounts receivable, net of allowance for doubtful
Accounts of $1,265 and $1,681, respectively		143,532			155,941
Inventories		14,611			15,260
Fair value contracts		2,152			1,581
Income tax receivable		1,868			2,171
Prepayments and other		9,768			10,804

Total current assets		202,234			202,563

Property and equipment		143,815			132,660
Less – accumulated depreciation,
depletion and amortization		(98,257	)		(90,355	)
		45,558			42,305
Other assets:
Deferred income tax asset		480			1,290
Cash deposits and other		2,628			3,243
	$	250,900		$	249,401

LIABILITIES AND SHAREHOLDERS’ EQUITY

Current liabilities:
Accounts payable	$	149,870		$	158,176
Accounts payable – related party		87			75
Fair value contracts		1,393			1,331
Accrued and other liabilities		5,767			3,872
Current deferred income taxes		1,057			737
Total current liabilities		158,174			164,191

Other liabilities:
Asset retirement obligations		1,372			1,315
Deferred taxes and other		1,312			94
		160,858			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		77,927			71,686
Total shareholders’ equity		90,042			83,801
	$	250,900		$	249,401

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

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

	Nine Months Ended
	September 30,
	2010			2009
CASH PROVIDED BY OPERATIONS:
Net earnings	$	6,241		$	5,243
Adjustments to reconcile net earnings to net cash
from operating activities -
Depreciation, depletion and amortization		8,425			7,517
Gains on property sales		(129	)		(93	)
Dry hole costs incurred		418			365
Impairment of oil and gas properties		1,817			2,761
Provision for doubtful accounts		2			12
Deferred income taxes		2,366			551
Net change in fair value contracts		(509	)		151
Other, net		(84	)		296
Decrease (increase) in accounts receivable		13,190			(18,535	)
Decrease (increase) in inventories		649			552
Decrease (increase) in income tax receivable		303			3,629
Decrease (increase) in prepayments		1,036			(4,455	)
Increase (decrease) in accounts payable		(8,606	)		28,636
Increase (decrease) in accrued liabilities		1,375			349

Net cash provided by operating activities		26,494			26,979

INVESTING ACTIVITIES:
Property and equipment additions		(13,085	)		(9,505	)
Insurance and state collateral (deposits) refunds		(45	)		587
Proceeds from property sales		133			459

Net cash (used in) investing activities		(12,997	)		(8,459	)

Increase in cash and cash equivalents		13,497			18,520

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

C Cash and cash equivalents at end of period	$	30,303		$	36,728

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

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED

CONSOLIDATED FINANCIAL STATEMENTS

Note 1 - Basis of Presentation

The accompanying condensed consolidated financial statements are unaudited but, in the opinion of the Company's management, include all adjustments (consisting of normal recurring accruals) necessary for the fair presentation of its financial position at September 30, 2010, its results of operations for the three and nine-month periods ended September 30, 2010 and 2009 and its cash flows for the nine months ended September 30, 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 unaudited condensed consolidated financial statements of events occurring after September 30, 2010 has been evaluated through the date these financials were issued.

Although the Company believes the disclosures made are adequate to make the information presented not misleading, it is suggested that these condensed 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 condensed 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 September 30, 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 financial 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):

	September 30,		December 31,
	2010		2009
Crude oil	$	12,668	$	14,053
Petroleum products		1,943		1,207

	$	14,611	$	15,260

Prepayments

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

	September 30,		December 31,
	2010		2009

Cash collateral deposits for commodity purchases	$	5,150	$	7,670
Insurance premiums		2,447		2,478
Natural gas pipeline imbalances		1,237		89
Rents, license and other		934		567

	$	9,768	$	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 September 30, 2010, the Company had no unevaluated or suspended exploratory drilling 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. Cash flows are developed based on estimated future production and prices and then discounted using an internal rate of return consistent with that used by the Company in evaluating cash flows for other assets of a similar nature. For the nine-month periods ended September 30, 2010 and 2009 there were $886,000 and $517,000 impairment provisions on producing oil and gas properties, respectively. Such provisions also totaled $880,000 and $295,000 for the three-month periods ended September 30, 2010 and 2009, 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 $931,000 and $2,244,000 were recorded for the nine-month periods ended September 30, 2010 and 2009, respectively. Such provisions totaled $148,000 and $1,570,000 for the three-month periods ended September 30, 2010 and 2009. 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 its 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):

	September 30,		December 31,
	2010		2009
Insurance collateral deposits	$	2,015	$	2,648
State collateral deposits		166		271
Materials and supplies		447		324
	$	2,628	$	3,243

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 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 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.

Concentration of Credit Risk

The Company’s largest customers consist of large multinational integrated oil companies and utilities. In addition, the Company transacts business with independent oil producers, major chemical concerns, crude oil and natural gas trading companies and a variety of commercial energy users. Within this group of customers the Company generally derives up to 50 percent of its revenues from two to three large crude oil refining concerns. While the Company has ongoing established relationships with certain domestic refiners of crude oil, alternative markets are readily available since the Company supplies less than one percent of U. S. domestic refiner demand. As a fungible commodity delivered to major Gulf Coast supply points, the Company’s crude oil sales can be readily delivered to alternative end markets. Management believes that a loss of any of those customers where the Company currently derives more than 10 percent of its revenues would not have a material adverse effect on the Company’s operations.

Accounts receivable associated with crude oil and natural gas marketing activities comprise approximately 90 percent of the Company’s total receivables and industry practice requires payment for such sales to occur within 25 days of the end of the month following a transaction. The Company’s customer makeup, credit policies and the relatively short duration of receivables mitigate the uncertainty typically associated with receivables management.

Letter of Credit Facility

The Company maintains a Credit and Security Agreement with Wells Fargo Bank to provide a $40 million stand-by letter of credit facility. The Wells Fargo facility provides for the issuance of up to $40 million of stand-by letters of credit to support the Company’s crude oil and natural gas purchases within the marketing segment. This facility is collateralized by the eligible accounts receivable within those operations. Stand-by letters of credit issued totaled $22.6 million as of September 30, 2010. The issued stand-by letters of credit are cancelled as the underlying purchase obligations are satisfied by cash payment when due. 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 excluding inventory valuation changes, as defined, among other restrictions. Management believes the Company is currently in compliance with all such covenants.

Statement of Cash Flows

Interest paid totaled $32,000 and $23,000 during the nine-month periods ended September 30, 2010 and 2009, respectively. Income taxes paid during these same periods totaled $275,000 and $549,000, respectively. The Company also received a $2,000,000 income tax refund during the first nine months of 2009. Non-cash investing activities for property and equipment in accounts payable were $312,000 and $439,000 as of September 30, 2010 and 2009, respectively; and in addition, such activities were $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 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 September 30, 2010 as follows (in thousands):

	Balance Sheet Location and Amount
	Current			Other		Current			Other
	Assets			Assets		Liabilities			Liabilities
Asset Derivatives
- Fair Value Commodity
Contracts at Gross Valuation	$	3,035		$	-	$	-		$	-

Liability Derivatives
- Fair Value Commodity
Contracts at Gross Valuation		-			-		2,276			-

Less Counterparty Offsets		(883	)		-		(883	)		-

As Reported Fair Value Contracts	$	2,152		$	-	$	1,393		$	-

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed 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 creditworthy counterparties or obtains collateral support for such activities. No credit loss provision applies to the Company’s forward commodity contract valuations. As of September 30, 2010 and December 31, 2009, the Company was not holding nor had it posted any collateral to support its forward month fair value derivative activity. The Company is not subject to any credit-risk related trigger events.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Statement of Operations for the nine and three months ended September 30, 2010 as follows (in thousands):

	Earnings (Loss)		Earnings (Loss)
	Nine Months Ended		Three Months Ended
	September 30,		September 30,
Location	2010	2009	2010	2009

Revenues - marketing	$ 509	$ (151)	$ 667	$ -

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 indices, third party price survey data and broker provided forward price statistics.

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

As of September 30, 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	$	-		$	2,152		$	-	$	2,152
- Current liabilities		(400	)		(993	)		-		(1,393	)
Net Value	$	(400	)	$	1,159		$	-	$	759

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 September 30, 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.

Certain producing oil and gas property costs with a carrying amount of $3,384,000 were written down to their fair value of $2,504,000, resulting in pretax impairment charges of $880,000 for the nine months ended September 30, 2010. Significant Level 3 assumptions associated with the calculation of discounted cash flows used in the impairment analysis include the Company’s estimate of future natural gas prices, production costs, development expenditures, anticipated production of proved reserves appropriate risk-adjusted discount rates and other relevant data.

New Accounting Pronouncements

Management believes the impact of 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. Information concerning the Company’s various business activities is summarized as follows (in thousands):

- Nine Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended September 30, 2010
Marketing
- Crude Oil	$	1,429,146	$	8,307		$	1,634	$	3,199
- Natural gas		8,410		2,253			43		87
- Refined products		94,374		153			382		143
Marketing Total		1,531,930		10,713			2,059		3,429
Transportation		43,372		5,122			3,333		263
Oil and gas		8,079		76			3,033		9,393
	$	1,583,381	$	15,911		$	8,425	$	13,085
Period Ended September 30, 2009
Marketing
- Crude Oil	$	1,304,092	$	13,425		$	1,527	$	724
- Natural gas		10,310		2,197			124		-
- Refined products		77,051		477			398		177
Marketing Total		1,391,453		16,099			2,049		901
Transportation		33,701		1,678			2,852		2,593
Oil and gas		6,356		(2,557	)		2,616		6,011
	$	1,431,510	$	15,220		$	7,517	$	9,505

- Three Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended September 30, 2010
Marketing
- Crude Oil	$	449,458	$	3,861		$	578	$	1,521
- Natural gas		2,534		847			1		58
- Refined products		32,420		(62	)		128		-
Marketing Total		484,412		4,646			707		1,579
Transportation		15,288		2,108			1,108		180
Oil and gas		2,755		(476	)		1,060		3,301
	$	502,455	$	6,278		$	2,875	$	5,060
Period Ended September 30, 2009
Marketing
- Crude Oil	$	530,981	$	3,582		$	496	$	74
- Natural gas		3,112		192			41		-
- Refined products		28,741		78			131		-
Marketing Total		562,834		3,852			668		74
Transportation		11,471		1,244			1,011		800
Oil and gas		1,994		(1,698	)		858		1,351
	$	576,299	$	3,398		$	2,537	$	2,225

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

	Nine Months ended						Three months ended
	September 30,						September 30,
	2010			2009			2010			2009
Segment operating earnings	$	15,911		$	15,220		$	6,278		$	3,398
- General and administrative		(6,659	)		(6,946	)		(2,257	)		(2,252	)
Operating earnings		9,252			8,274			4,021			1,146
- Interest income		110			138			80			82
- Interest expense		(32	)		(23	)		(1	)		(15	)
Earnings before income tax	$	9,330		$	8,389		$	4,100		$	1,213

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

	September 30,		December 31,
	2010		2009
Marketing
- Crude oil	$	132,952	$	130,840
- Natural gas		21,491		40,715
- Refined products		12,608		10,133
Marketing Total		167,051		181,688
Transportation		15,511		16,078
Oil and gas		30,917		26,050
Other		37,421		25,585
	$	250,900	$	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 nine month periods of 2010 and 2009, the Company’s investment commitments totaled approximately $9.4 million and $5.3 million, respectively, in those oil and gas projects where a related party was also participating in such investments. As of September 30, 2010 and December 31, 2009, the Company owed a combined net total of $87,000 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 $118,000 and $111,000 in the nine-month periods ended September 30, 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 secretarial services. For the nine-month period ended September 30, 2010 and 2009, the affiliated entities charged the Company $32,000 and $54,000, respectively, of expense reimbursement and the Company charged the affiliates $88,000 and $98,000, 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 September 30, 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):

	Nine Months Ended				Three Months Ended
	September 30,				September 30,
	2010		2009		2010			2009
Revenues
Crude oil	$	1,429,146	$	1,304,092	$	449,458		$	530,981
Natural gas		8,410		10,310		2,534			3,112
Refined products		94,374		77,051		32,420			28,741
Total	$	1,531,930	$	1,391,453	$	484,412		$	562,834

Operating Earnings
Crude oil	$	8,307	$	13,425	$	3,861		$	3,582
Natural gas		2,253		2,197		847			192
Refined products		153		477		(62	)		78
Total	$	10,713	$	16,099	$	4,646		$	3,852

Depreciation
Crude oil	$	1,634	$	1,527	$	578		$	496
Natural gas		43		124		1			41
Refined products		382		398		128			131
Total	$	2,059	$	2,049	$	707		$	668

Supplemental volume and price information is as follows:

	Nine Months Ended				Three Months Ended
	September 30,				September 30,
	2010		2009		2010		2009
Field Level Purchase Volumes – Per day (1)
Crude oil – barrels		67,300		66,200		65,700		64,100
Natural gas – mmbtu’s		268,600		383,000		268,600		369,000

Average Purchase Price
Crude oil – per barrel	$	75.19	$	53.14	$	73.71	$	65.41
Natural Gas – per mmbtu’s	$	4.44	$	3.63	$	4.21	$	3.12

_____________________________

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

Crude oil revenues were elevated by 10 percent in the current nine-month period, while they were reduced by 15 percent in the current three-month period relative to the same periods last year. In contrast, average crude oil prices were elevated in both the comparative nine-month and three-month periods by 42 percent and 13 percent, respectively, as shown in the table above. Volumes were relatively consistent between the comparative periods. This apparent conflicting data is explained by the accounting requirement to reflect certain buy/sell arrangements on a net revenue basis. As a result, a change in the Company’s customer mix will increase or decrease comparative reported revenues. During 2010 a larger portion of sales were reported on a net revenue basis, substantially offsetting the effect of increased average prices.

While revenues are increased for 2010, the total accounts receivable balance of $143,532,000 as of September 30, 2010 is reduced from the total accounts receivable balance of $155,941,000 as of December 31, 2009. Total accounts receivable, which include the activities of all segments, were reduced in September 2010 relative to December 2009 because natural gas sales volumes were reduced in 2010. Commodity sales of natural gas are designated as trading activity and are therefore reported on a net revenue basis only. As a result, reduced natural gas volumes do not noticeably impact gross revenues while they do noticeably impact accounts receivable comparisons.

The effect of crude oil prices on operating earnings during the nine month period of 2010 was nominal as the average acquisition price of crude oil moved from the $74 per barrel level at the beginning of the year to $75 per barrel for September 2010. For the nine-month period of 2010 inventory liquidation gains totaled $47,000. While overall crude oil prices in the current year were generally flat, during the 2009 period, crude oil prices consistently rose from the $41 per barrel range in January to the $69 per barrel range in September 2009 producing a $4,912,000 inventory liquidation gain of which $849,000 occurred in the third quarter.

The impact on crude oil operating earnings from inventory liquidation gains is summarized as follows:

	Nine Months Ended						Three Months Ended
	September 30,						September 30,
	2010			2009			2010			2009
As Reported Operating
Earnings	$	8,307		$	13,425		$	3,861		$	3,582

Inventory Liquidation (Gains)		(47	)		(4,912	)		(1	)		(849	)

Comparative Operating
Earnings	$	8,260		$	8,513		$	3,860		$	2,733

Excluding the impact of inventory values, comparative crude oil operating earnings were consistent for the comparative nine-month periods with improvement reflected in the current quarter relative to last year. Current period operating earnings benefited from improved unit margin opportunities and the reversal of $710,000 in previously recorded accrual items following the final accounting true-up of such items. As of September 30, 2010 the Company held 168,591 barrels of crude oil inventory at an average price of $75.14 per barrel.

Natural gas sales are reported net of underlying natural gas purchase costs and thus reflect gross margin. As shown above, except for the third quarter of 2010 such margins were reduced during 2010 as average field level purchase volumes were off 30 percent for the period (see table above). Current volumes have declined because the Company’s suppliers have 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. In contrast to the general trend, during the third quarter of 2010, the Company was able to adjust its marketplace strategy and recapture some of its margin opportunities which bolstered operating earnings.

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):

	Nine Months Ended							Three Months Ended
	September 30,				Increase			September 30,				Increase
	2010		2009		(Decrease)			2010		2009		(Decrease)

Revenues	$	43,372	$	33,701		28.7	%	$	15,288	$	11,471		33.3	%

Operating earnings	$	5,122	$	1,678		205.2	%	$	2,108	$	1,244		69.4	%

Depreciation	$	3,333	$	2,852		16.8	%	$	1,108	$	1,011		9.6	%

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 results 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 approximately $11.8 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 100 replacement units at an estimated cost of $11 million is also planned for the fourth 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):

	Nine Months Ended								Three Months Ended
	September 30,					Increase			September 30,						Increase
	2010		2009			(Decrease)			2010			2009			(Decrease)
Revenues	$	8,079	$	6,356			27.1	%	$	2,755		$	1,994			38.2	%

Operating earnings (loss)	$	76	$	(2,557	)		102.9	%	$	(476	)	$	(1,698	)		71.9	%

Depreciation and depletion	$	3,033	$	2,616			15.9	%	$	1,060		$	858			23.5	%

The revenue and earnings improvement for the oil and gas segment is attributable to crude oil and natural gas price increases as shown in the table below. Operating earnings in 2010 also benefited from reduced exploration and impairment expenses as shown in the second table below.

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

	Nine Months Ended				Three Months Ended
	September 30,				September 30,
	2010		2009		2010		2009
Crude Oil
Volume – barrels		40,605		39,148		14,602		11,521
Average price per barrel	$	75.04	$	54.00	$	72.78	$	65.14

Natural gas
Volume – mcf		967,051		981,918		324,865		316,002
Average price per mcf	$	5.20	$	4.32	$	5.21	$	3.94

Comparative exploration and impairment costs were as follows (in thousands):

	Nine Months Ended				Three Months Ended
	September 30,				September 30,
	2010		2009		2010		2009
Dry hole expense	$	418	$	365	$	116	$	60
Prospect impairments		1,817		2,761		1,028		1,865
Seismic and geological		54		676		31		172

Total	$	2,289	$	3,802	$	1,175	$	2,097

During the first nine months of 2010, the Company participated in the drilling of 29 successful wells with six dry holes. Additionally, the Company has an interest in 23 wells that were in process on September 30, 2010. Evaluation on the in-process wells is anticipated during the fourth quarter of 2010. Participation in the drilling of approximately 10 wells is planned for the remainder of 2010 on the Company’s prospect acreage in Arkansas, Kansas, Louisiana and Texas.

- Outlook

The marketing and transportation segments have been performing at expected levels and business currently looks to be holding firm. Increased crude oil production in the Company’s South Texas area of marketing operations is also occurring as the Eagle Ford shale play is being developed in the region. In contrast to the recent strength in the crude oil markets, natural gas prices have been in decline falling below $4 per mcf. At such prices, the Company’s future oil and gas segment operating earnings will be reduced and reduced drilling activity is planned for 2011.

Liquidity and Capital Resources

The Company’s liquidity primarily derives from net cash provided by operating activities and such amount was $26,494,000 and $26,979,000, respectively, for each of the nine-month periods ended September 30, 2010 and 2009. As of September 30, 2010 and December 31, 2009, the Company had no bank debt or other forms of debenture obligations. Cash and cash equivalents totaled $30,303,000 as of September 30, 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 $44,060,000 as of September 30, 2010.

Capital expenditures during the nine-month period of 2010 included $3,692,000 for marketing and transportation equipment additions and $9,393,000 in property additions associated with oil and gas exploration and production activities. For the remainder of 2010, the Company anticipates expending an additional approximate $3 million on oil and gas exploration projects to be funded from operating cash flow and available working capital. In addition, approximately $11 million will be expended during the fourth quarter of 2010 for the purchase of 100 trucks-tractors for the transportation segment and approximately $1.5 million will be expended for the purchase of eight tractors and eight trailers for the marketing segment with funding for such purchase from available cash flow. The units will serve to increase the marketing segment fleet.

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 $5,150,000 as of September 30, 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 $3,100,000 as of September 30, 2010. The Company also maintains a stand-by letter of credit facility with Wells Fargo Bank to provide for the issuance of stand-by letters of credit to the Company’s suppliers of crude oil and natural gas (see Note 1 to Financial Statements). The issuance of stand-by letters of credit enables the Company to avoid posting cash collateral when procuring crude oil and natural gas supply. As of September 30, 2010, letters of credit outstanding totaled $22.6 million. 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 and this comprises 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 $1.6 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 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 Company’s 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 September 30, 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) 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, 2009, under “Item 1A Risk Factors” 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 Securities and Exchange Commission’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 the disclosure controls and procedures as of the end of the period covered by this report are effective to ensure that information required to be disclosed in the Company’s Exchange Act filings is recorded, processed, summarized and reported within the periods specified in the Securities and Exchange Commission’s rules and forms.

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 September 30, 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, 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: November 12, 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