10-Q

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, 2013

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.)

17 South Briar Hollow Lane Suite 100, Houston, Texas  77027

(Address of principal executive office & Zip Code)

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

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.  See the definitions of ‟large accelerated filer”, ‟accelerated filer” and ‟smaller reporting company” in Rule 12b-2 of the Exchange Act.  (Check one):

Large accelerated filer o   Accelerated filer x   Non-accelerated filer o   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 5, 2013.

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,
	2013			2012			2013			2012
REVENUES:
Marketing	$	2,917,328		$	2,442,884		$	1,039,767		$	774,732
Transportation		51,795			50,137			16,906			16,741
Oil and natural gas		11,022			11,467			4,097			4,052
		2,980,145			2,504,488			1,060,770			795,525
COSTS AND EXPENSES:
Marketing		2,876,266			2,407,607			1,026,558			759,669
Transportation		42,053			38,032			13,871			12,560
Oil and gas operations		4,659			5,670			1,698			1,948
Oil and gas property sale (gain)		-			(475	)		-			(475	)
General and administrative		7,504			7,300			2,535			2,603
Depreciation, depletion and amortization		16,294			14,639			5,373			5,450
		2,946,776			2,472,773			1,050,035			781,755
Operating earnings		33,369			31,715			10,735			13,770
Other income (expense):
Interest income		103			120			33			78
Interest expense		(24	)		(4	)		(1	)		(1	)
Earnings from continuing operations before income taxes		33,448			31,831			10,767			13,847
Income tax (provision)		(12,109	)		(11,947	)		(3,797	)		(5,510	)
Earnings from continuing operations		21,339			19,884			6,970			8,337
Earnings (loss) from discontinued operations net of tax
(provision) benefit of  $(87), ($183), $(100) and $40,
Respectively		162			340			186			(74	)
Net earnings	$	21,501		$	20,224		$	7,156		$	8,263
EARNINGS (LOSS) PER SHARE:
From continuing operations		5.06		$	4.71		$	1.65		$	1.98
From discontinued operations		.04			.08			.05			(.02	)
Basic and diluted net earnings per common share	$	5.10		$	4.79		$	1.70		$	1.96
DIVIDENDS PER COMMON SHARE	$	.44		$	-		$	.22		$	-

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

1

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

	September 30,			December 31,
	2013			2012
ASSETS
Current assets:
Cash and cash equivalents	$	52,044		$	47,239
Accounts receivable, net of allowance for doubtful
accounts of $278 and $206, respectively		287,853			239,319
Inventory		24,095			28,222
Fair value contracts		555			418
Income tax receivable		1,866			1,199
Prepayments		8,584			8,092
Current assets of discontinued operations		-			67
Total current assets		374,997			324,556
Property and Equipment
Marketing		53,561			46,177
Transportation		59,240			59,101
Oil and gas (successful efforts method)		98,647			90,431
Other		1,305			1,406
		212,753			197,115
Less – Accumulated depreciation, depletion and amortization		(117,053	)		(106,403	)
		95,700			90,712
Other Assets:
Deferred income tax asset		142			34
Cash deposits and other		3,841			4,199
	$	474,680		$	419,501
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities:
Accounts payable	$	286,517		$	258,310
Accounts payable – related party		48			42
Fair value contracts		39			412
Accrued and other liabilities		12,053			7,078
Current deferred income taxes		503			240
Total current liabilities		299,160			266,082
Other Liabilities:
Asset retirement obligations		1,917			1,886
Deferred taxes and other liabilities		18,099			15,675
		319,176			283,643
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		143,389			123,743
Total shareholders’ equity		155,504			135,858
	$	474,680		$	419,501

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

2

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

	Nine Months Ended
	September 30,
	2013			2012
CASH PROVIDED BY OPERATIONS:
Net earnings	$	21,501		$	20,224
Adjustments to reconcile net earnings to net cash
from operating activities -
Depreciation, depletion and amortization		16,294			14,639
Property sale (gains)		(480	)		(4,364	)
Dry hole costs incurred		105			43
Impairment of oil and gas properties		414			878
Provision for doubtful accounts		72			(49	)
Deferred income taxes		2,598			3,728
Net change in fair value contracts		(510	)		2,555
Decrease (increase) in accounts receivable		(48,539	)		34,740
Decrease (increase) in inventories		4,127			(7,516	)
Decrease (increase) in income tax receivable		(667	)		417
Decrease (increase) in prepayments		(492	)		1,480
Increase (decrease) in accounts payable		28,493			(22,797	)
Increase (decrease) in accrued liabilities		5,660			6,870
Other changes, net		549			394
Net cash provided by operating activities		29,125			51,242
INVESTING ACTIVITIES:
Property and equipment additions		(23,133	)		(43,129	)
Insurance and state collateral (deposits) refunds		(179	)		268
Proceeds from property sales		847			3,061
Proceeds from the sale of discontinued operations		-			3,546
Net cash (used in) investing activities		(22,465	)		(36,254	)
FINANCING ACTIVITIES:
Dividend payments		(1,855	)		-
Net cash (used in) financing activities		(1,855	)		-
Increase (decrease) in cash and cash equivalents		4,805			14,988
Cash and cash equivalents at beginning of period		47,239			37,066
Cash and cash equivalents at end of period	$	52,044		$	52,054

The accompanying notes are an integral part of these financial statements

3

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED

CONSOLIDATED FINANCIAL STATEMENTS

Note 1 - Basis of Presentation

The accompanying unaudited condensed consolidated financial statements, 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, 2013, its results of operations for the nine months ended September 30, 2013 and 2012 and its cash flows for the nine months ended September 30, 2013 and 2012. Certain information and note disclosures normally included in annual financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted pursuant to Securities and Exchange Commission rules and regulations.  The impact on the accompanying financial statements of events occurring after September 30, 2013, has been evaluated through the date these financial statements were issued.

Although the Company believes the disclosures made are adequate to make the information presented not misleading, it is suggested that these unaudited 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 and natural gas 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 unaudited 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 intercompany accounts and transactions.

Cash and Cash Equivalents

Cash and cash equivalents include any Treasury bill, commercial paper, money market fund or federal funds with maturity of 90 days or less.  Depending on cash availability and market conditions, investments in corporate and municipal bonds, which are classified as investments in marketable securities, may also be made from time to time.  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.

Inventory

Inventory consists of crude oil held in storage tanks and at third-party pipelines as part of the Company’s crude oil marketing operations.  Crude oil inventory is carried at the lower of average cost or market.

4

Prepayments

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

	September 30,		December 31,
	2013		2012
Cash collateral deposits for commodity purchases	$	5,000	$	5,000
Insurance premiums		2,753		1,872
Commodity imbalances and futures		11		353
Rents, license and other		820		867
	$	8,584	$	8,092

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 is removed from the accounts and any gain or loss is reflected in earnings.

At various times during 2012, the Company sold certain used trucks and equipment from its transportation and marketing truck fleets and recorded pre-tax gains totaling $4,364,000.  Such sales were substantially reduced during 2013.

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, 2013, the Company had no unevaluated or suspended exploratory drilling costs.

Depreciation, depletion and amortization of the cost of proved oil and gas properties are 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 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 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 are then discounted using a market based 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, 2013 and 2012, there were $216,000 and $90,000, respectively, of impairment provisions on producing oil and gas properties.  Such impairment provisions were $74,000 and $19,000 for the three-month periods ended September 30, 2013.

5

On a quarterly basis, management evaluates the carrying value of non-producing oil and gas leasehold properties and may deem them impaired based on remaining lease term, area drilling activity and the Company’s plans for the property.  This fair value measure depends highly on management’s assessment of the likelihood of continued exploration efforts in a given area and, as such, data inputs are categorized as unobservable or Level 3 inputs.  Importantly, this fair value measure only applies to the write-down of capitalized costs and will never result in an increase to reported earnings. Accordingly, impairment provisions on non-producing properties totaling $198,000 and $788,000 were recorded for the nine-month periods ended September 30, 2013 and 2012, respectively.  Such impairment provisions were $98,000 and $230,000 for the three-month periods ended September 30, 2013.  Capitalized costs for non-producing oil and gas leasehold interests currently represent approximately four percent of total oil and gas property costs and are categorized as follows (in thousands):

	September 30,		December 31,
	2013		2012
South Texas Project acreage	$	3,669	$	3,263
West Texas Project acreage		129		180
Napoleonville, Louisiana acreage		162		323
Other acreage areas		398		329
Total Non-producing Leasehold Costs	$	4,358	$	4,095

The South Texas, West Texas and Napoleonville acreage areas have active or scheduled drilling operations underway and holding the underlying acreage is essential to the ongoing exploration effort.  The ‟other acreage areas” category consists of smaller onshore interests dispersed over a wide geographical area.  Since the Company is generally not the operator of its oil and gas property interest, it does not maintain the underlying detail acreage data and the Company is dependent on the operator when determining which specific acreage will ultimately be drilled.  However, the capitalized cost detail on a property-by-property basis is reviewed by management, and deemed impaired if development is not anticipated prior to lease expiration.  Onshore leasehold periods are normally three years and may contain renewal options.  Capitalized cost activity on the ‟other acreage areas” was as follows (in thousands):

	Leasehold
	Costs
Balance December 31, 2012	$	329
Property additions		267
Impairments		(198	)
Balance September 30, 2013	$	398

6

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.  Insurance collateral deposits are invested at the discretion of the Company’s insurance carrier and such investments primarily consist of intermediate term federal government bonds and bonds backed by federal agencies.  Components of cash deposits and other assets are as follows (in thousands):

	September 30,		December 31,
	2013		2012
Insurance collateral deposits	$	3,084	$	3,413
State collateral deposits		166		170
Materials and supplies		591		616
	$	3,841	$	4,199

7

Revenue Recognition

Certain 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 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.

Most crude oil purchase contracts and sale contracts qualify and are designated as non-trading activities and the Company considers such contracts as normal purchases and sales activity.  For normal purchases and sales, 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, 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 unaudited condensed consolidated financial statements.  Reporting such crude oil contracts on a gross revenue basis would increase the Company’s reported revenues by $1,176,156,000 and $714,489,000 for the nine months ended September 30, 2013 and 2012, respectively.

Transportation segment 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 95 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.

8

Letter of Credit Facility

The Company maintains a Credit and Security Agreement with Wells Fargo Bank to provide a $60 million stand-by letter of credit facility that is used 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 and certain marketing and transportation equipment.  Stand-by letters of credit issued totaled $15.4 million and $21.9 million as of September 30, 2013 and December 31, 2012, respectively.  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.  The Company is currently in compliance with all such financial covenants.

Statement of Cash Flows

Interest paid totaled $24,000 and $4,000 during the nine-month periods ended September 30, 2013 and 2012, respectively, while taxes paid during these same periods totaled $9,863,000 and $6,636,000, respectively.  Non-cash investing activities for property and equipment were $1,454,000 and $2,419,000 as of September 30, 2013 and December 31, 2012, respectively and $2,962,000 and $4,070,000 as of September 30, 2012 and December 31, 2011, 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 presented herein. The weighted average number of shares outstanding was 4,217,596 for 2013 and 2012.  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 oil and gas reserve volumes forming the foundation for calculating depreciation, depletion and amortization and for estimating cash flows when assessing impairment triggers and when estimating values associated with oil and gas properties.  Other examples include revenue accruals, the provision for bad debts, insurance related accruals, income tax permanent and timing differences, contingencies and valuation of fair value contracts.

Income Taxes

Income taxes are accounted for using the asset and liability method.  Under this approach, deferred tax assets and liabilities are recognized based on anticipated future tax consequences attributable to differences between financial statement carrying amounts of assets and liabilities and their respective tax basis.

9

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.  Certain of 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.  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, 2013 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	$	555	$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-		-		(39	)		-
Less Counterparty Offsets		-		-		-			-
As Reported Fair Value Contracts	$	555	$	-	$	(39	)	$	-

As of September 30, 2013, one 100,000 barrel crude oil commodity put option and one commodity purchase and sale contract comprised the Company’s derivative valuations.  The purchase and sale contract encompasses approximately 175 barrels of crude oil per day in each of October, November and December 2013 and January and February 2014, respectively.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Balance Sheet as of December 31, 2012 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	$	688		$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-			-		682			-
Less Counterparty Offsets		(270	)		-		(270	)		-
As Reported Fair Value Contracts	$	418		$	-	$	412		$	-

10

As of December 31, 2012, twenty-four commodity purchase and sales contracts comprise all of the Company’s derivative valuations.  Such contracts encompass the purchase and sale of approximately 900 barrels of crude oil per day and 172,000 mmbtu of natural gas per day during January 2013 with crude oil volumes continuing at the rate of 200 barrels per day through June 2013 together with natural gas volumes of 1,000 mmbtu and 41,000 mmbtu per day in February 2013 and March 2013, respectively.

The Company only enters into commodity contracts with credit worthy counterparties or obtains collateral support for such activities.  As of September 30, 2013 and December 31, 2012, 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.  The Company has no other financial investment arrangements that would serve to offset its derivative contracts.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Statement of Operations for the nine months ended September 30, 2013 and 2012 as follows (in thousands):

	Earnings (Loss)						Earnings (Loss)
	Nine Months Ended						Three Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Revenues – marketing	$	(105	)	$	(2,555	)	$	(103	)	$	(1,562	)

Fair Value Measurements

The carrying amount reported in the balance sheet for cash and cash equivalents, accounts receivable and accounts payable approximates fair value because of the immediate or short-term maturity of these financial instruments.  Marketable securities are recorded at fair value based on market quotations from actively traded liquid markets.

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.  For Level 1 valuation of marketable securities, the Company utilizes market quotations provided by its primary financial institution and for the valuation of derivative financial instruments the Company utilizes the New York Mercantile Exchange (NYMEX) for such valuations.

11

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 NYMEX, the 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, 2013, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets		Total
Derivatives
- Current assets	$	-	$	555		$	-	$	-	$	555
- Current liabilities		-		(39	)		-		-		(39	)
Net Value	$	-	$	516		$	-	$	-	$	516

As of December 31, 2012, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets			Total
Derivatives
- Current assets	$	299	$	389		$	-	$	(270	)	$	418
- Current liabilities		-		(682	)		-		270			(412	)
Net Value	$	299	$	(293	)	$	-	$	-		$	6

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, 2013 and December 31, 2012, 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 are included in their entirety in the fair value hierarchy.

Recent Accounting Pronouncement

In December 2011, the Financial Accounting Standards Board (“FASB”) issued ASU 2011-11.  This update requires additional disclosures about an entity’s right of setoff and related arrangements associated with its financial and derivative instruments.  The ASU requires a tabular presentation that reflects the gross, net and setoff amounts associated with such assets and liabilities among other requirements.  The Company adopted ASU 2011-11 effective January 1, 2013 and the adoption of ASU 2011-11 did not have a material impact on the Company’s consolidated financial statements, but additional disclosures regarding fair value measurements resulted.

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.

12

Note 3 – Segment Reporting

The Company is engaged in the business of crude oil and natural gas 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, 2013
Marketing
- Crude Oil	$	2,915,056	$	35,509		$	5,517	$	9,512
- Natural gas		2,272		(111	)		147		-
Marketing Total		2,917,328		35,398			5,664		9,512
Transportation		51,795		4,479			5,263		3,162
Oil and gas		11,022		996			5,367		10,459
	$	2,980,145	$	40,873		$	16,294	$	23,133
Period Ended September 30, 2012
Marketing
- Crude Oil	$	2,438,815	$	29,880		$	4,324	$	9,079
- Natural gas		4,069		1,057			16		-
Marketing Total		2,442,884		30,937			4,340		9,079
Transportation		50,137		7,919			4,186		15,484
Oil and gas		11,467		159			6,113		18,566
	$	2,504,488	$	39,015		$	14,639	$	43,129

- Three Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended September 30, 2013
Marketing
- Crude Oil	$	1,039,337	$	11,394		$	1,939	$	932
- Natural gas		430		(124	)		-		-
Marketing Total		1,039,767		11,270			1,939		932
Transportation		16,906		1,248			1,787		1,589
Oil and gas		4,097		752			1,647		4,314
	$	1,060,770	$	13,270		$	5,373	$	6,835
Period Ended September 30, 2012
Marketing
- Crude Oil	$	773,611	$	13,278		$	1,596	$	1,673
- Natural gas		1,121		174			15		-
Marketing Total		774,732		13,452			1,611		1,673
Transportation		16,741		2,607			1,574		4,740
Oil and gas		4,052		314			2,265		5,106
	$	795,525	$	16,373		$	5,450	$	11,519

13

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

	Nine Months Ended						Three Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Segment operating earnings (loss)	$	40,873		$	39,015		$	13,270		$	16,373
- General and administrative		(7,504	)		(7,300	)		(2,535	)		(2,603	)
Operating earnings		33,369			31,715			10,735			13,770
- Interest income		103			120			33			78
- Interest expense		(24	)		(4	)		(1	)		(1	)
Earnings from continuing operations
before income taxes and
discontinued operations	$	33,448		$	31,831		$	10,767		$	13,847

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

	September 30,		December 31,
	2013		2012
Marketing
- Crude oil	$	329,893	$	277,920
- Natural gas		8,496		11,764
Marketing Total		338,389		289,684
Transportation		37,019		38,940
Oil and gas		38,962		35,788
Other		60,310		55,089
	$	474,680	$	419,501

Intersegment sales are insignificant and all sales occurred in the United States.  Other identifiable assets are primarily corporate cash, corporate accounts receivable and properties not identified with any specific segment of the Company’s business.  Accounting policies for transactions between reportable segments are consistent with applicable accounting policies as disclosed herein.

Note 4 - Transactions with Affiliates

The late Mr. K. S. Adams, Jr., former Chairman of the Board of the Company, and certain of his family partnerships and affiliates have participated as working interest owners with the Company’s subsidiary, Adams Resources Exploration Corporation.  Mr. Adams and such affiliates participate on terms similar to those afforded other non-affiliated working interest owners. In recent years, such related party transactions generally result after the Company has first identified oil and gas prospects of interest.  Typically the available dollar commitment to participate in such transactions is greater than the amount management is comfortable putting at risk.  In such event, the Company first determines the percentage of the transaction it wants to obtain, which allows a related party to participate in the investment to the extent there is excess available.  In those instances where there was no excess availability there has been no related party participation.  Similarly, related parties are not required to participate, nor is the Company obligated to offer any such participation to a related or other party.  When such related party transactions occur, they are individually reviewed and approved by the Audit Committee comprised of the independent directors on the Company’s Board of Directors.  For the first nine months of 2013 and 2012, the Company’s investment commitments totaled approximately $10.4 million and $18.3 million, respectively, in those oil and gas projects where a related party was also participating in such investments.  As of September 30, 2013 and December 31, 2012, the Company owed a combined net total of $48,000 and $42,000, 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 Bulletin 5. Such overhead recoveries totaled $119,000 and $113,000 for the nine-month periods ended September 30, 2013 and 2012, respectively.

14

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 periods ended September 30, 2013 and 2012, the affiliated entities charged the Company $54,000 and $52,000, respectively, of expense reimbursement and the Company charged the affiliates $75,000 and $73,000, respectively, for such expense reimbursements.  In January 2012, the Company relocated its primary office lease space to a building operated by an affiliated entity.  Estimated annual rental expense, including pro rata building operating expense are $480,000 per year under a seven year lease term.  The lease rental rate was determined by an independent appraisal.  Rental expense paid to such related party for the nine months ended September 30, 2013 and 2012 totaled $360,000 and $322,000, respectively.

Note 5 - Commitments and Contingencies

Under the Company’s automobile and workers’ compensation insurance policies, the Company can either receive a return of premium paid or be assessed for additional premiums up to pre-established limits. Additionally, in certain instances the risk of insured losses is shared with a group of similarly situated entities.  The Company has appropriately recognized estimated expenses and related liabilities for losses incurred but not reported to the Company or its insurance carrier of $966,000 and $1,545,000 as of September 30, 2013 and December 31, 2012, respectively.

Effective January 1, 2012, the Company began a self-insurance program for managing employee medical claims.  On a monthly basis, the Company establishes a liability for expected claims incurred.  As claims are paid, the liability is relieved.  As of September 30, 2013 and December 31, 2012, accrued medical claims totaled $973,000 and $506,000, respectively.  The Company maintains third party insurance stop-loss coverage for annual individual medical claims exceeding $100,000.  In addition, the Company maintains $2 million of umbrella insurance coverage for aggregate medical claims exceeding approximately $4.5 million for the calendar year 2013.

From time to time as incidental to its operations, the Company may become 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.

Note 6 – Discontinued Operation

On February 27, 2012, the Company completed the sale of contracts, inventory and certain equipment associated with the refined products segment of its marketing business.  Revenues from this segment included in net earnings from discontinued operations totaled $25,633,000 for the three-month period ended March 31, 2012.  The Company received $2 million in cash proceeds plus a cash payment of $1,546,000 for the agreed value of refined product inventories on the date of sale.  The net gain recognized upon this sale totaled $1,622,000.  The Company conducted an orderly wind-down of the operation which primarily consisted of collecting outstanding accounts receivable and satisfying all existing obligations.  The Company’s fee interest in certain parcels of real estate was retained and the estimated fair value of such properties exceeded the Company’s cost basis in the properties.  Therefore, an impairment assessment of long-lived assets was not necessary.  The proceeds secured from this transaction exceeded the sum of carrying costs of the assets sold plus severance and other wind-down costs and as a result, the first quarter 2012 pre-tax earnings from this former segment totaled $808,000.  Retained accounts receivable and payable obligations were substantially collected or satisfied as of the date of this report.

15

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 and certain costs are as follows (in thousands):

	Nine Months Ended					Three Months Ended
	September 30,					September 30,
	2013			2012		2013			2012
Revenues
Crude oil	$	2,915,056		$	2,438,815	$	1,039,337		$	773,611
Natural gas		2,272			4,069		430			1,121
Total	$	2,917,328		$	2,442,884	$	1,039,767		$	774,732
Operating Earnings
Crude oil	$	35,509		$	29,880	$	11,394		$	13,278
Natural gas		(111	)		1,057		(124	)		174
Total	$	35,398		$	30,937	$	11,270		$	13,452
Depreciation
Crude oil	$	5,517		$	4,324	$	1,939		$	1,596
Natural gas		147			16		-			15
Total	$	5,664		$	4,340	$	1,939		$	1,611
Crude oil operation
fleet fuel costs	$	10,216		$	8,295	$	3,524		$	2,824

Supplemental volume and price information is as follows:

	Nine Months Ended				Three Months Ended
	September 30,				September 30,
	2013		2012		2013		2012
Field Level Purchase Volumes – Per day (1)
Crude oil – barrels		104,160		87,022		107,772		86,301
Natural gas – mmbtu’s		106,850		130,566		129,204		94,568
Average Purchase Price
Crude oil – per barrel	$	101.94	$	100.90	$	104.76	$	96.44
Natural Gas – per mmbtu’s	$	3.61	$	2.40	$	3.60	$	2.75

_____________________________

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

Crude oil revenues increased during 2013 with increased volumes and prices as shown in the table above.  Volume increases resulted from new well production developed by the Company’s customer base primarily in the Eagle Ford shale trend of South Texas coupled with the establishment of a new area of operation in the Bakken field of North Dakota.

16

-   Crude Oil – Field Level Operating Earnings (Non GAAP Measure)

Two significant factors affecting comparative crude oil segment operating earnings are inventory valuations and forward commodity contract (derivatives or mark-to-market) valuations.  As a purchaser and shipper of crude oil, the Company holds inventory in storage tanks and third-party pipelines.  Inventory sales turnover occurs approximately every three days, but the quantity held in stock at the end of a given period is reasonably consistent.  As a result, during periods of increasing crude oil prices, the Company recognizes inventory liquidation gains while during periods of falling prices, the Company recognizes inventory valuation losses.  Over time, these gains and losses tend to offset and have limited impact on cash flow.  While crude oil prices fluctuated during the first nine months of 2013, the net impact yielded inventory liquidation gains totaling $471,000 as prices increased from $95 per barrel in January 2013 to a composite average of $103 per barrel in September 2013 for all grades of crude oil held by the Company.  In contrast, crude oil prices were generally declining during the first portion of 2012 producing inventory valuation losses of $1,543,000 for the comparative period.  As of September 30, 2013, the Company held 234,209 barrels of crude oil inventory at a composite average price of $102.87 per barrel.

Crude oil marketing operating earnings are also affected by the valuations of the Company’s forward month commodity contracts (derivative instruments) as of the various report dates.  Such non-cash valuations are calculated and recorded at each period end based on the underlying data existing as of such date.  The Company generally enters into these derivative contracts as part of a pricing strategy based on crude oil purchases at the wellhead (field level).  Only those contracts qualifying as derivative instruments are accorded fair value treatment while the companion contracts to purchase crude oil at the wellhead (field level) are not accorded fair value treatment.  The valuation of derivative instruments at period end requires the recognition of ‟mark-to-market” gains and losses.  The impact on crude oil segment operating earnings of inventory liquidations and derivative valuations is summarized as follows (in thousands):

	Nine Months Ended					Three Months Ended
	September 30,					September 30,
	2013			2012		2013			2012
As reported segment operating earnings
Add (less) -	$	35,509		$	29,880	$	11,394		$	13,278
Inventory valuation (gains) losses		(471	)		1,543		(851	)		(3,217	)
Derivative valuation (gains) losses		73			3,278		72			1,509
Field level operating earnings(1)	$	35,111		$	34,701	$	10,615		$	11,570

____________________________________

(1)   Such designation is unique to the Company and is not comparable to any similar measures developed by industry participants.

Field level operating earnings and field level purchase volumes (see earlier table) depict the Company’s day-to-day operation of acquiring crude oil at the wellhead, transporting the material, and delivery to market at the sales point.  Comparative crude oil field level operating earnings increased in 2013 relative to 2012 with the noted volume additions.  However, unit margins narrowed during 2013 with higher fuel costs and additional industry infrastructure development stiffening competition.  The Company anticipates continued volume growth from South Texas and North Dakota sourced production as these regions continue to develop, although competition should narrow margins.

Historically, prices received for crude oil and natural gas have been volatile and unpredictable with price volatility expected to continue.  See Item 1A Risk Factors in the Annual Report on Form 10-K for the year ended December 31, 2012.

17

-           Natural Gas

Following management’s decision to implement an orderly wind-down of its natural gas marketing business, the 2013 operating losses resulted from the accrual of approximately $537,000 in shut-down and severance expense of which $257,000 was recorded during the third quarter.  The shut-down process is expected to be completed in November 2013 and no material adverse effect is anticipated following this action.

-           Transportation

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

	Nine Months Ended							Three Months Ended
	September 30,				Increase			September 30,				Increase
	2013		2012		(Decrease)			2013		2012		(Decrease)
Revenues	$	51,795	$	50,137		3.3	%	$	16,906	$	16,741		1.0	%
Operating earnings	$	4,479	$	7,919		(43.4	)%	$	1,248	$	2,607		(52.1	)%
Depreciation	$	5,263	$	4,186		25.7	%	$	1,787	$	1,574		13.5	%

Customer demand and revenues for the transportation segment were consistent and strong during the comparative periods.  However, the prior period benefitted from gains on the sale of used truck-tractors totaling $2,399,000 during the full period with gains totaling $1,070,000 occurring during the third quarter.  Such sales did not recur in 2013.  Additionally, 2013 sustained higher depreciation charges as new equipment was placed in service during 2012.  The transportation segment is currently benefiting from the present low price environment for natural gas because this commodity is a basic feed stock for the Company’s petrochemical industry customer base.  The petrochemical industry has been expanding capacity and the long-term prospect for demand for chemical hauling services remains positive.  Presently, the Company is operating below full capacity with the availability of qualified drivers the significant constraint.

-           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
	2013		2012			(Decrease)			2013		2012			(Decrease)
Revenues	$	11,022	$	11,467			(3.9	)%	$	4,097	$	4,052			1.1	%
Operating earnings (loss)	$	996	$	(316	)		415.1	%	$	752	$	(161	)		567.1	%
Gains from property sales	$	-	$	475			N/C		$	-	$	475			N/C
Depreciation and depletion	$	5,367	$	6,113			(12.2	)%	$	1,647	$	2,265			(27.3	)%

18

Oil and gas segment revenues declined for the current nine month comparative period with reduced overall volumes.  However, revenues and operating earnings improved especially during the third quarter of 2013 on strengthened crude oil revenues as shown in the table below.

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

	Nine Months Ended				Three Months Ended
	September 30,				September 30,
	2013		2012		2013		2012
Crude Oil(1)
Volume – barrels		77,781		69,012		29,680		27,545
Average price per barrel	$	78.65	$	87.59	$	88.65	$	79.76
Natural gas
Volume – mcf		1,309,023		1,939,167		384,406		642,661
Average price per mcf	$	3.75	$	2.80	$	3.81	$	2.89

__________________________________

(1)   Crude oil volumes and prices included the value of associated natural gas liquids production.

Comparative exploration costs are summarized in the table below.  Exploration cost components were as follows (in thousands):

	Nine Months Ended				Three Months Ended
	September 30,				September 30,
	2013		2012		2013		2012
Dry hole expense	$	105	$	43	$	-	$	2
Prospect and property impairments		414		878		172		249
Seismic and geological		113		83		23		1
Total	$	632	$	1,004	$	195	$	252

During the first nine months of 2013, the Company participated in the drilling of 58 successful wells with two dry holes.  Additionally, the Company has an interest in 25 wells that were in process on September 30, 2013.  Evaluation on the in-process wells is anticipated during the fourth quarter of 2013.  Participation in the drilling of approximately 34 wells is planned for the remainder of 2013 on the Company’s prospect acreage in Texas, Kansas, Arkansas, Louisiana and Wyoming.

-           Discontinued Operation

During the first quarter of 2012, the Company sold contracts, inventory and certain equipment associated with its refined products market segment and discontinued that operation.  The pre-tax gain from this sale, net of first quarter 2012 operating expenses and wind-down cost totaled $808,000.  See also Note 6 – Discontinued Operations to Unaudited Condensed Consolidated Financial Statements.

-           Outlook

Crude oil marketing operations anticipate steady volume growth but competition continues to narrow unit margins by as much as one-third.  Demand for transportation services remains strong but driver shortages and persistently high operating cost has dampened profitability within this segment.  From the oil and gas segment, growth in crude oil production volumes should lead to continued earnings improvement.

19

Liquidity and Capital Resources

The Company’s liquidity primarily derives from net cash provided by operating activities and such amount was $29,125,000 and $51,242,000 for the respective nine-month periods ended September 30, 2013 and 2012.  During the comparative current period, net cash from operating activities was reduced relative to the prior period when the Company utilized available cash balances to fund the acquisition of additional quantities of crude oil supply.  As of September 30, 2013 and December 31, 2012, the Company had no bank debt or other forms of debenture obligations.  Cash and cash equivalents totaled $52,044,000 as of September 30, 2013, 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 $75,837,000 as of September 30, 2013.  The Company heavily relies on its ability to obtain open-line trade credit from its suppliers especially with respect to its crude oil marketing operation.  In this regard, the Company generally maintains substantial cash balances and avoids debt obligations.

Capital expenditures during the first nine months of 2013 included $12,674,000 for marketing and transportation equipment additions and $10,459,000 in property additions associated with oil and gas exploration and production activities.  Over the course of the next three months, the Company anticipates expending approximately $3 million on oil and gas exploration projects with no significant capital items planned for the marketing and transportation segments during the four quarter.

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 $5,000,000 as of September 30, 2013.  Prepayment amounts are recouped and advanced from day-to-day as the suppliers deliver product to the Company.  In addition, in order to secure crude oil supply, the Company may also ‟early pay” its suppliers in advance of the normal payment due date of the twentieth of the month following the month of production.  Such ‟early payments” serve to reduce accounts payable as of the balance sheet date.  The Company also requires certain counterparties to make similar early payments or to post cash collateral with the Company in order to support their purchases from the Company.  Early payments received from customers serve to reduce accounts receivable as of the balance sheet date.  Management believes current cash balances, together with expected cash generated from future operations and the ease of financing truck and trailer additions through leasing arrangements (should the need arise) 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 an approximate $9.9 million commitment for storage tank terminal arrangements and office lease space, the Company’s future commitments and planned investments can be readily curtailed if operating cash flows contract.

Historically, the Company has paid an annual dividend in the fourth quarter of each year and a dividend of $.62 per common share or $2,615,000 was paid to shareholders in December 2012.  On June 17, 2013, the Company initiated a quarterly dividend of $.22 per common share or $928,000.  A quarterly dividend of $.22 per common share or $928,000 was also paid during the third quarter of 2013.  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, 2012.

Critical Accounting Policies and Use of Estimates

There have 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, 2012.

20

Item 3.  Quantitative and Qualitative Disclosures about Market Risk

There have 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, 2012.

Forward-Looking Statements – Safe Harbor Provisions

This quarterly report for the period ended September 30, 2013 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, 2012, 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 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.  Management necessarily applied its judgment in assessing the costs and benefit of such controls and procedures, which, by their nature, can provide only reasonable assurance regarding management’s disclosure control objectives.

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 Company’s disclosure controls and procedures were effective at a reasonable assurance level as of the end of the period covered by this report.

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, 2013 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

21

PART II.  OTHER INFORMATION

Item 1.  Legal Proceedings

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.   Risk Factors  - 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, 2012.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds – None

Item 3. Defaults Upon Senior Securities – None

Item 4. Mine Safety Disclosures – Not Applicable

Item 5. Other Information – None

Item 6. Exhibits

The exhibits listed in the accompanying Exhibit Index are filed or incorporated by reference as part of this Quarterly Report on Form 10-Q.

22

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 8, 2013	By /s/Frank T. Webster
	Frank T. Webster
	President, Chief Executive Officer
	and Chief Operating Officer
	(Principal Executive Officer)
	By /s/Richard B. Abshire
	Richard B. Abshire
	Chief Financial Officer
	(Principal Financial Officer and Principal
	Accounting Officer)

23

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

*    **101.INS-	XBRL Instance Document
*    **101.SCH -	XBRL Schema Document
*    **101.CAL -	XBRL Calculation Linkbase Document
*    **101.LAB -	XBLR Label Linkbase Document
*    **101.PRE -	XBRL Presentation Linkbase Document

* Exhibits filed herewith

**      Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) the Consolidated Statements of Income – Nine Months Ended September 30, 2013 and 2012, (ii) the Consolidated Balance Sheets – September 30, 2013 and December 31, 2012, (iii) the Consolidated Statements of Cash Flows – Nine Months Ended September 30, 2013 and 2012 and (iv) Notes to Consolidated Financial Statements.

EX-31.1

 Exhibit 31.1

ADAMS RESOURCES & ENERGY, INC.

CERTIFICATION PURSUANT TO

17 CFR 240.13a-14(a)/15d-14(a)

AS ADOPTED PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Frank T. Webster certify that:

1. I have reviewed this quarterly report on Form 10-Q of Adams Resources & Energy, Inc. (‟the registrant”);

2. Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this quarterly report;

3. Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this quarterly report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)), for the registrant and have:

(a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this quarterly report is being prepared;

(b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)  evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)  disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

(a)  all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)  any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  November 8, 2013

/s/ Frank T. Webster

Frank T. Webster

Chief Executive Officer

EX-31.2

Exhibit 31.2

ADAMS RESOURCES & ENERGY, INC.

CERTIFICATION PURSUANT TO

17 CFR 240.13a-14(a)/15d-14(a)

AS ADOPTED PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Richard B. Abshire, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Adams Resources & Energy, Inc. (‟the registrant”);

2. Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this quarterly report;

3. Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this quarterly report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)), for the registrant and have:

(a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this quarterly report is being prepared;

(b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)  evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)  disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

(a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  November 8, 2013

/s/ Richard B. Abshire

Richard B. Abshire

Chief Financial Officer

EX-32.1

Exhibit 32.1

ADAMS RESOURCES & ENERGY, INC.

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Adams Resources & Energy, Inc. (the ‟Company”) on Form 10-Q for the period ending September 30, 2013, as filed with the Securities and Exchange Commission (the “Report”), I, Frank T. Webster, Chief Executive Officer of the Company, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350) that to the best of my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Frank T. Webster

Frank T. Webster

Chief Executive Officer

Date:  November 8, 2013

This Certification is being furnished solely to accompany the Report pursuant to 18 U.S.C.§1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, and shall not be deemed filed by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and shall not be incorporated by reference into any filing of the Company under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, whether made before or after the date of this Report, irrespective of any general incorporation language contained in such filing.

A signed original of this written statement required by Section 906, or other documents authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

ADAMS RESOURCES & ENERGY, INC.

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Adams Resources & Energy, Inc. (the ‟Company”) on Form 10-Q for the period ending September 30, 2013, as filed with the Securities and Exchange Commission (the “Report”), I, Richard B. Abshire, Chief Financial Officer of the Company, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350), that to the best of my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended ; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Richard B. Abshire

Richard B. Abshire

Chief Financial Officer

Date:  November 8, 2013

This Certification is being furnished solely to accompany the Report pursuant to 18 U.S.C.§1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, and shall not be deemed filed by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and shall not be incorporated by reference into any filing of the Company under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, whether made before or after the date of this Report, irrespective of any general incorporation language contained in such filing.

A signed original of this written statement required by Section 906, or other documents authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Summary of Significant Accounting Policies, Derivatives by Hedging Relationship and Fair Value Measurements (Details) (USD $) In Thousands, unless otherwise specified											3 Months Ended		9 Months Ended
	Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Level 1 Quoted Prices [Member]	Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Level 1 Quoted Prices [Member]	Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Level 2 Observable [Member]	Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Level 2 Observable [Member]	Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Level 3 Unobservable [Member]	Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Level 3 Unobservable [Member]	Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Counterparty Offsets [Member]	Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Counterparty Offsets [Member]	Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Total Fair Value [Member]	Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Total Fair Value [Member]	Sep. 30, 2013 Commodity Contract [Member] Revenues - marketing [Member] Not Designated as Hedging Instrument [Member]	Sep. 30, 2012 Commodity Contract [Member] Revenues - marketing [Member] Not Designated as Hedging Instrument [Member]	Sep. 30, 2013 Commodity Contract [Member] Revenues - marketing [Member] Not Designated as Hedging Instrument [Member]	Sep. 30, 2012 Commodity Contract [Member] Revenues - marketing [Member] Not Designated as Hedging Instrument [Member]
Earnings (loss) recognized in income [Abstract]
Earnings (Loss)											$ (103)	$ (1,562)	$ (105)	$ (2,555)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives - Current assets	0	299	555	389	0	0	0	(270)	555	418
Derivatives - Current liabilities	0	0	(39)	(682)	0	0	0	270	(39)	(412)
Net Value	$ 0	$ 299	$ 516	$ (293)	$ 0	$ 0	$ 0	$ 0	$ 516	$ 6

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UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Current assets:
Cash and cash equivalents	$ 52,044	$ 47,239
Accounts receivable, net of allowance for doubtful accounts of $278 and $206, respectively	287,853	239,319
Inventory	24,095	28,222
Fair value contracts	555	418
Income tax receivable	1,866	1,199
Prepayments	8,584	8,092
Current assets of discontinued operations	0	67
Total current assets	374,997	324,556
Property and Equipment
Marketing	53,561	46,177
Transportation	59,240	59,101
Oil and gas (successful efforts method)	98,647	90,431
Other	1,305	1,406
Property and equipment	212,753	197,115
Less - Accumulated depreciation, depletion and amortization	(117,053)	(106,403)
Net property and equipment	95,700	90,712
Other Assets:
Deferred income tax asset	142	34
Cash deposits and other	3,841	4,199
Total Assets	474,680	419,501
Current Liabilities:
Accounts payable	286,517	258,310
Accounts payable - related party	48	42
Fair value contracts	39	412
Accrued and other liabilities	12,053	7,078
Current deferred income taxes	503	240
Total current liabilities	299,160	266,082
Other Liabilities:
Asset retirement obligations	1,917	1,886
Deferred taxes and other liabilities	18,099	15,675
Total liabilities	319,176	283,643
Commitments and Contingencies (Note 5)
Shareholders' Equity:
Preferred stock - $1.00 par value, 960,000 shares authorized, none outstanding	0	0
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	143,389	123,743
Total shareholders' equity	155,504	135,858
Liabilities and shareholders' equity	$ 474,680	$ 419,501

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Transactions with Affiliates

9 Months Ended

Sep. 30, 2013

Transactions with Affiliates [Abstract]

Transactions with Affiliates

Note 4 - Transactions with Affiliates

The late Mr. K. S. Adams, Jr., former Chairman of the Board of the Company, and certain of his family partnerships and affiliates have participated as working interest owners with the Company’s subsidiary, Adams Resources Exploration Corporation.  Mr. Adams and such affiliates participate on terms similar to those afforded other non-affiliated working interest owners. In recent years, such related party transactions generally result after the Company has first identified oil and gas prospects of interest.  Typically the available dollar commitment to participate in such transactions is greater than the amount management is comfortable putting at risk.  In such event, the Company first determines the percentage of the transaction it wants to obtain, which allows a related party to participate in the investment to the extent there is excess available.  In those instances where there was no excess availability there has been no related party participation.  Similarly, related parties are not required to participate, nor is the Company obligated to offer any such participation to a related or other party.  When such related party transactions occur, they are individually reviewed and approved by the Audit Committee comprised of the independent directors on the Company’s Board of Directors.  For the first nine months of 2013 and 2012, the Company’s investment commitments totaled approximately $10.4 million and $18.3 million, respectively, in those oil and gas projects where a related party was also participating in such investments.  As of September 30, 2013 and December 31, 2012, the Company owed a combined net total of $48,000 and $42,000, 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 Bulletin 5. Such overhead recoveries totaled $119,000 and $113,000 for the nine-month periods ended September 30, 2013 and 2012, 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 periods ended September 30, 2013 and 2012, the affiliated entities charged the Company $54,000 and $52,000, respectively, of expense reimbursement and the Company charged the affiliates $75,000 and $73,000, respectively, for such expense reimbursements.  In January 2012, the Company relocated its primary office lease space to a building operated by an affiliated entity.  Estimated annual rental expense, including pro rata building operating expense are $480,000 per year under a seven year lease term.  The lease rental rate was determined by an independent appraisal.  Rental expense paid to such related party for the nine months ended September 30, 2013 and 2012 totaled $360,000 and $322,000, respectively.

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Segment Reporting (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Activities by Segment [Abstract]
Revenues	$ 1,060,770	$ 795,525	$ 2,980,145	$ 2,504,488
Segment operating earnings (loss)	13,270	16,373	40,873	39,015
Depreciation Depletion and Amortization	5,373	5,450	16,294	14,639
Property and Equipment Additions	6,835	11,519	23,133	43,129
Segment operating earnings [Abstract]
General and administrative expenses	(2,535)	(2,603)	(7,504)	(7,300)
Operating earnings	10,735	13,770	33,369	31,715
Interest income	33	78	103	120
Interest expense	(1)	(1)	(24)	(4)
Earnings from continuing operations before income taxes	10,767	13,847	33,448	31,831
Identifiable assets by segment [Abstract]
Assets	474,680		474,680		419,501
Marketing [Member]
Activities by Segment [Abstract]
Revenues	1,039,767	774,732	2,917,328	2,442,884
Segment operating earnings (loss)	11,270	13,452	35,398	30,937
Depreciation Depletion and Amortization	1,939	1,611	5,664	4,340
Property and Equipment Additions	932	1,673	9,512	9,079
Identifiable assets by segment [Abstract]
Assets	338,389		338,389		289,684
Marketing [Member] | Crude Oil [Member]
Activities by Segment [Abstract]
Revenues	1,039,337	773,611	2,915,056	2,438,815
Segment operating earnings (loss)	11,394	13,278	35,509	29,880
Depreciation Depletion and Amortization	1,939	1,596	5,517	4,324
Property and Equipment Additions	932	1,673	9,512	9,079
Identifiable assets by segment [Abstract]
Assets	329,893		329,893		277,920
Marketing [Member] | Natural Gas [Member]
Activities by Segment [Abstract]
Revenues	430	1,121	2,272	4,069
Segment operating earnings (loss)	(124)	174	(111)	1,057
Depreciation Depletion and Amortization	0	15	147	16
Property and Equipment Additions	0	0	0	0
Identifiable assets by segment [Abstract]
Assets	8,496		8,496		11,764
Transportation [Member]
Activities by Segment [Abstract]
Revenues	16,906	16,741	51,795	50,137
Segment operating earnings (loss)	1,248	2,607	4,479	7,919
Depreciation Depletion and Amortization	1,787	1,574	5,263	4,186
Property and Equipment Additions	1,589	4,740	3,162	15,484
Identifiable assets by segment [Abstract]
Assets	37,019		37,019		38,940
Oil and Gas [Member]
Activities by Segment [Abstract]
Revenues	4,097	4,052	11,022	11,467
Segment operating earnings (loss)	752	314	996	159
Depreciation Depletion and Amortization	1,647	2,265	5,367	6,113
Property and Equipment Additions	4,314	5,106	10,459	18,566
Identifiable assets by segment [Abstract]
Assets	38,962		38,962		35,788
Other [Member]
Identifiable assets by segment [Abstract]
Assets	$ 60,310		$ 60,310		$ 55,089

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UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
CASH PROVIDED BY OPERATIONS:
Net earnings	$ 21,501	$ 20,224
Adjustments to reconcile net earnings to net cash from operating activities -
Depreciation, depletion and amortization	16,294	14,639
Property sale (gains)	(480)	(4,364)
Dry hole costs incurred	105	43
Impairment of oil and gas properties	414	878
Provision for doubtful accounts	72	(49)
Deferred income taxes	2,598	3,728
Net change in fair value contracts	(510)	2,555
Decrease (increase) in accounts receivable	(48,539)	34,740
Decrease (increase) in inventories	4,127	(7,516)
Decrease (increase) in income tax receivable	(667)	417
Decrease (increase) in prepayments	(492)	1,480
Increase (decrease) in accounts payable	28,493	(22,797)
Increase (decrease) in accrued liabilities	5,660	6,870
Other changes, net	549	394
Net cash provided by operating activities	29,125	51,242
INVESTING ACTIVITIES:
Property and equipment additions	(23,133)	(43,129)
Insurance and state collateral (deposits) refunds	(179)	268
Proceeds from property sales	847	3,061
Proceeds from the sale of discontinued operations	0	3,546
Net cash (used in) investing activities	(22,465)	(36,254)
FINANCING ACTIVITIES:
Dividend payments	(1,855)	0
Net cash (used in) financing activities	(1,855)	0
Increase (decrease) in cash and cash equivalents	4,805	14,988
Cash and cash equivalents at beginning of period	47,239	37,066
Cash and cash equivalents at end of period	$ 52,044	$ 52,054

XML

Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2013

Summary of Significant Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Note 2 - Summary of Significant Accounting Policies

Nature of Operations and Principles of Consolidation

The Company is engaged in the business of crude oil and natural gas 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 unaudited 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 intercompany accounts and transactions.

Cash and Cash Equivalents

Cash and cash equivalents include any Treasury bill, commercial paper, money market fund or federal funds with maturity of 90 days or less.  Depending on cash availability and market conditions, investments in corporate and municipal bonds, which are classified as investments in marketable securities, may also be made from time to time.  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.

Inventory

Inventory consists of crude oil held in storage tanks and at third-party pipelines as part of the Company’s crude oil marketing operations.  Crude oil inventory is carried at the lower of average cost or market.

Prepayments

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

	September 30,		December 31,
	2013		2012
Cash collateral deposits for commodity purchases	$	5,000	$	5,000
Insurance premiums		2,753		1,872
Commodity imbalances and futures		11		353
Rents, license and other		820		867
	$	8,584	$	8,092

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 is removed from the accounts and any gain or loss is reflected in earnings.

At various times during 2012, the Company sold certain used trucks and equipment from its transportation and marketing truck fleets and recorded pre-tax gains totaling $4,364,000.  Such sales were substantially reduced during 2013.

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, 2013, the Company had no unevaluated or suspended exploratory drilling costs.

Depreciation, depletion and amortization of the cost of proved oil and gas properties are 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 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 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 are then discounted using a market based 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, 2013 and 2012, there were $216,000 and $90,000, respectively, of impairment provisions on producing oil and gas properties.  Such impairment provisions were $74,000 and $19,000 for the three-month periods ended September 30, 2013.

On a quarterly basis, management evaluates the carrying value of non-producing oil and gas leasehold properties and may deem them impaired based on remaining lease term, area drilling activity and the Company’s plans for the property.  This fair value measure depends highly on management’s assessment of the likelihood of continued exploration efforts in a given area and, as such, data inputs are categorized as unobservable or Level 3 inputs.  Importantly, this fair value measure only applies to the write-down of capitalized costs and will never result in an increase to reported earnings. Accordingly, impairment provisions on non-producing properties totaling $198,000 and $788,000 were recorded for the nine-month periods ended September 30, 2013 and 2012, respectively.  Such impairment provisions were $98,000 and $230,000 for the three-month periods ended September 30, 2013.  Capitalized costs for non-producing oil and gas leasehold interests currently represent approximately four percent of total oil and gas property costs and are categorized as follows (in thousands):

	September 30,		December 31,
	2013		2012
South Texas Project acreage	$	3,669	$	3,263
West Texas Project acreage		129		180
Napoleonville, Louisiana acreage		162		323
Other acreage areas		398		329
Total Non-producing Leasehold Costs	$	4,358	$	4,095

The South Texas, West Texas and Napoleonville acreage areas have active or scheduled drilling operations underway and holding the underlying acreage is essential to the ongoing exploration effort.  The ‟other acreage areas” category consists of smaller onshore interests dispersed over a wide geographical area.  Since the Company is generally not the operator of its oil and gas property interest, it does not maintain the underlying detail acreage data and the Company is dependent on the operator when determining which specific acreage will ultimately be drilled.  However, the capitalized cost detail on a property-by-property basis is reviewed by management, and deemed impaired if development is not anticipated prior to lease expiration.  Onshore leasehold periods are normally three years and may contain renewal options.  Capitalized cost activity on the ‟other acreage areas” was as follows (in thousands):

	Leasehold
	Costs
Balance December 31, 2012	$	329
Property additions		267
Impairments		(198	)
Balance September 30, 2013	$	398

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.  Insurance collateral deposits are invested at the discretion of the Company’s insurance carrier and such investments primarily consist of intermediate term federal government bonds and bonds backed by federal agencies.  Components of cash deposits and other assets are as follows (in thousands):

	September 30,		December 31,
	2013		2012
Insurance collateral deposits	$	3,084	$	3,413
State collateral deposits		166		170
Materials and supplies		591		616
	$	3,841	$	4,199

Revenue Recognition

Certain 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 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.

Most crude oil purchase contracts and sale contracts qualify and are designated as non-trading activities and the Company considers such contracts as normal purchases and sales activity.  For normal purchases and sales, 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, 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 unaudited condensed consolidated financial statements.  Reporting such crude oil contracts on a gross revenue basis would increase the Company’s reported revenues by $1,176,156,000 and $714,489,000 for the nine months ended September 30, 2013 and 2012, respectively.

Transportation segment 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 95 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 $60 million stand-by letter of credit facility that is used 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 and certain marketing and transportation equipment.  Stand-by letters of credit issued totaled $15.4 million and $21.9 million as of September 30, 2013 and December 31, 2012, respectively.  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.  The Company is currently in compliance with all such financial covenants.

Statement of Cash Flows

Interest paid totaled $24,000 and $4,000 during the nine-month periods ended September 30, 2013 and 2012, respectively, while taxes paid during these same periods totaled $9,863,000 and $6,636,000, respectively.  Non-cash investing activities for property and equipment were $1,454,000 and $2,419,000 as of September 30, 2013 and December 31, 2012, respectively and $2,962,000 and $4,070,000 as of September 30, 2012 and December 31, 2011, 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 presented herein. The weighted average number of shares outstanding was 4,217,596 for 2013 and 2012.  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 oil and gas reserve volumes forming the foundation for calculating depreciation, depletion and amortization and for estimating cash flows when assessing impairment triggers and when estimating values associated with oil and gas properties.  Other examples include revenue accruals, the provision for bad debts, insurance related accruals, income tax permanent and timing differences, contingencies and valuation of fair value contracts.

Income Taxes

Income taxes are accounted for using the asset and liability method.  Under this approach, deferred tax assets and liabilities are recognized based on anticipated future tax consequences attributable to differences between financial statement carrying amounts of assets and liabilities and their respective tax basis.

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.  Certain of 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.  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, 2013 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	$	555	$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-		-		(39	)		-
Less Counterparty Offsets		-		-		-			-
As Reported Fair Value Contracts	$	555	$	-	$	(39	)	$	-

As of September 30, 2013, one 100,000 barrel crude oil commodity put option and one commodity purchase and sale contract comprised the Company’s derivative valuations.  The purchase and sale contract encompasses approximately 175 barrels of crude oil per day in each of October, November and December 2013 and January and February 2014, respectively.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Balance Sheet as of December 31, 2012 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	$	688		$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-			-		682			-
Less Counterparty Offsets		(270	)		-		(270	)		-
As Reported Fair Value Contracts	$	418		$	-	$	412		$	-

As of December 31, 2012, twenty-four commodity purchase and sales contracts comprise all of the Company’s derivative valuations.  Such contracts encompass the purchase and sale of approximately 900 barrels of crude oil per day and 172,000 mmbtu of natural gas per day during January 2013 with crude oil volumes continuing at the rate of 200 barrels per day through June 2013 together with natural gas volumes of 1,000 mmbtu and 41,000 mmbtu per day in February 2013 and March 2013, respectively.

The Company only enters into commodity contracts with credit worthy counterparties or obtains collateral support for such activities.  As of September 30, 2013 and December 31, 2012, 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.  The Company has no other financial investment arrangements that would serve to offset its derivative contracts.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Statement of Operations for the nine months ended September 30, 2013 and 2012 as follows (in thousands):

	Earnings (Loss)						Earnings (Loss)
	Nine Months Ended						Three Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Revenues – marketing	$	(105	)	$	(2,555	)	$	(103	)	$	(1,562	)

Fair Value Measurements

The carrying amount reported in the balance sheet for cash and cash equivalents, accounts receivable and accounts payable approximates fair value because of the immediate or short-term maturity of these financial instruments.  Marketable securities are recorded at fair value based on market quotations from actively traded liquid markets.

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.  For Level 1 valuation of marketable securities, the Company utilizes market quotations provided by its primary financial institution and for the valuation of derivative financial instruments the Company utilizes the New York Mercantile Exchange (NYMEX) for such 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 NYMEX, the 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, 2013, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets		Total
Derivatives
- Current assets	$	-	$	555		$	-	$	-	$	555
- Current liabilities		-		(39	)		-		-		(39	)
Net Value	$	-	$	516		$	-	$	-	$	516

As of December 31, 2012, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets			Total
Derivatives
- Current assets	$	299	$	389		$	-	$	(270	)	$	418
- Current liabilities		-		(682	)		-		270			(412	)
Net Value	$	299	$	(293	)	$	-	$	-		$	6

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, 2013 and December 31, 2012, 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 are included in their entirety in the fair value hierarchy.

Recent Accounting Pronouncement

In December 2011, the Financial Accounting Standards Board (“FASB”) issued ASU 2011-11.  This update requires additional disclosures about an entity’s right of setoff and related arrangements associated with its financial and derivative instruments.  The ASU requires a tabular presentation that reflects the gross, net and setoff amounts associated with such assets and liabilities among other requirements.  The Company adopted ASU 2011-11 effective January 1, 2013 and the adoption of ASU 2011-11 did not have a material impact on the Company’s consolidated financial statements, but additional disclosures regarding fair value measurements resulted.

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.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2013

Commitments and Contingencies [Abstract]

Commitments and Contingencies

Note 5 - Commitments and Contingencies

Under the Company’s automobile and workers’ compensation insurance policies, the Company can either receive a return of premium paid or be assessed for additional premiums up to pre-established limits. Additionally, in certain instances the risk of insured losses is shared with a group of similarly situated entities.  The Company has appropriately recognized estimated expenses and related liabilities for losses incurred but not reported to the Company or its insurance carrier of $966,000 and $1,545,000 as of September 30, 2013 and December 31, 2012, respectively.

Effective January 1, 2012, the Company began a self-insurance program for managing employee medical claims.  On a monthly basis, the Company establishes a liability for expected claims incurred.  As claims are paid, the liability is relieved.  As of September 30, 2013 and December 31, 2012, accrued medical claims totaled $973,000 and $506,000, respectively.  The Company maintains third party insurance stop-loss coverage for annual individual medical claims exceeding $100,000.  In addition, the Company maintains $2 million of umbrella insurance coverage for aggregate medical claims exceeding approximately $4.5 million for the calendar year 2013.

From time to time as incidental to its operations, the Company may become 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.

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Segment Reporting

9 Months Ended

Sep. 30, 2013

Segment Reporting [Abstract]

Segment Reporting

Note 3 – Segment Reporting

The Company is engaged in the business of crude oil and natural gas 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, 2013
Marketing
- Crude Oil	$	2,915,056	$	35,509		$	5,517	$	9,512
- Natural gas		2,272		(111	)		147		-
Marketing Total		2,917,328		35,398			5,664		9,512
Transportation		51,795		4,479			5,263		3,162
Oil and gas		11,022		996			5,367		10,459
	$	2,980,145	$	40,873		$	16,294	$	23,133
Period Ended September 30, 2012
Marketing
- Crude Oil	$	2,438,815	$	29,880		$	4,324	$	9,079
- Natural gas		4,069		1,057			16		-
Marketing Total		2,442,884		30,937			4,340		9,079
Transportation		50,137		7,919			4,186		15,484
Oil and gas		11,467		159			6,113		18,566
	$	2,504,488	$	39,015		$	14,639	$	43,129

- Three Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended September 30, 2013
Marketing
- Crude Oil	$	1,039,337	$	11,394		$	1,939	$	932
- Natural gas		430		(124	)		-		-
Marketing Total		1,039,767		11,270			1,939		932
Transportation		16,906		1,248			1,787		1,589
Oil and gas		4,097		752			1,647		4,314
	$	1,060,770	$	13,270		$	5,373	$	6,835
Period Ended September 30, 2012
Marketing
- Crude Oil	$	773,611	$	13,278		$	1,596	$	1,673
- Natural gas		1,121		174			15		-
Marketing Total		774,732		13,452			1,611		1,673
Transportation		16,741		2,607			1,574		4,740
Oil and gas		4,052		314			2,265		5,106
	$	795,525	$	16,373		$	5,450	$	11,519

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

	Nine Months Ended						Three Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Segment operating earnings (loss)	$	40,873		$	39,015		$	13,270		$	16,373
- General and administrative		(7,504	)		(7,300	)		(2,535	)		(2,603	)
Operating earnings		33,369			31,715			10,735			13,770
- Interest income		103			120			33			78
- Interest expense		(24	)		(4	)		(1	)		(1	)
Earnings from continuing operations
before income taxes and
discontinued operations	$	33,448		$	31,831		$	10,767		$	13,847

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

	September 30,		December 31,
	2013		2012
Marketing
- Crude oil	$	329,893	$	277,920
- Natural gas		8,496		11,764
Marketing Total		338,389		289,684
Transportation		37,019		38,940
Oil and gas		38,962		35,788
Other		60,310		55,089
	$	474,680	$	419,501

Intersegment sales are insignificant and all sales occurred in the United States.  Other identifiable assets are primarily corporate cash, corporate accounts receivable and properties not identified with any specific segment of the Company’s business.  Accounting policies for transactions between reportable segments are consistent with applicable accounting policies as disclosed herein.

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UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Parenthetical) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS [Abstract]
Earnings (loss) from discontinued operations, tax	$ (100)	$ 40	$ (87)	$ (183)

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Summary of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2013

Summary of Significant Accounting Policies [Abstract]

Components of prepayments and other

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

	September 30,		December 31,
	2013		2012
Cash collateral deposits for commodity purchases	$	5,000	$	5,000
Insurance premiums		2,753		1,872
Commodity imbalances and futures		11		353
Rents, license and other		820		867
	$	8,584	$	8,092

Capitalized costs for non-producing oil and gas leasehold interests

Capitalized costs for non-producing oil and gas leasehold interests currently represent approximately four percent of total oil and gas property costs and are categorized as follows (in thousands):

	September 30,		December 31,
	2013		2012
South Texas Project acreage	$	3,669	$	3,263
West Texas Project acreage		129		180
Napoleonville, Louisiana acreage		162		323
Other acreage areas		398		329
Total Non-producing Leasehold Costs	$	4,358	$	4,095

Capitalized cost activity on the other acreage areas

Capitalized cost activity on the ‟other acreage areas” was as follows (in thousands):

	Leasehold
	Costs
Balance December 31, 2012	$	329
Property additions		267
Impairments		(198	)
Balance September 30, 2013	$	398

Components of cash deposits and other assets

Components of cash deposits and other assets are as follows (in thousands):

	September 30,		December 31,
	2013		2012
Insurance collateral deposits	$	3,084	$	3,413
State collateral deposits		166		170
Materials and supplies		591		616
	$	3,841	$	4,199

Derivatives reflected in the Consolidated Balance Sheet

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, 2013 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	$	555	$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-		-		(39	)		-
Less Counterparty Offsets		-		-		-			-
As Reported Fair Value Contracts	$	555	$	-	$	(39	)	$	-

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Balance Sheet as of December 31, 2012 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	$	688		$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-			-		682			-
Less Counterparty Offsets		(270	)		-		(270	)		-
As Reported Fair Value Contracts	$	418		$	-	$	412		$	-

Derivatives reflected in the Consolidated Statement of Operations

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Statement of Operations for the nine months ended September 30, 2013 and 2012 as follows (in thousands):

	Earnings (Loss)						Earnings (Loss)
	Nine Months Ended						Three Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Revenues – marketing	$	(105	)	$	(2,555	)	$	(103	)	$	(1,562	)

Fair value assets and liabilities

As of September 30, 2013, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets		Total
Derivatives
- Current assets	$	-	$	555		$	-	$	-	$	555
- Current liabilities		-		(39	)		-		-		(39	)
Net Value	$	-	$	516		$	-	$	-	$	516

As of December 31, 2012, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets			Total
Derivatives
- Current assets	$	299	$	389		$	-	$	(270	)	$	418
- Current liabilities		-		(682	)		-		270			(412	)
Net Value	$	299	$	(293	)	$	-	$	-		$	6

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UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $) In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Current assets:
Allowance for doubtful accounts	$ 278	$ 206
Shareholders' Equity:
Preferred stock - par value (in dollars per share)	$ 1.00	$ 1.00
Preferred stock - shares authorized (in shares)	960,000	960,000
Preferred stock - outstanding (in shares)	0	0
Common stock - par value (in dollars per share)	$ 0.10	$ 0.10
Common stock - shares authorized (in shares)	7,500,000	7,500,000
Common stock - shares outstanding (in shares)	4,217,596	4,217,596

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UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
REVENUES:
Marketing	$ 1,039,767	$ 774,732	$ 2,917,328	$ 2,442,884
Transportation	16,906	16,741	51,795	50,137
Oil and natural gas	4,097	4,052	11,022	11,467
Total revenues	1,060,770	795,525	2,980,145	2,504,488
COSTS AND EXPENSES:
Marketing	1,026,558	759,669	2,876,266	2,407,607
Transportation	13,871	12,560	42,053	38,032
Oil and gas operations	1,698	1,948	4,659	5,670
Oil and gas property sale (gain)	0	(475)	0	(475)
General and administrative	2,535	2,603	7,504	7,300
Depreciation, depletion and amortization	5,373	5,450	16,294	14,639
Total costs and expenses	1,050,035	781,755	2,946,776	2,472,773
Operating earnings	10,735	13,770	33,369	31,715
Other income (expense):
Interest income	33	78	103	120
Interest expense	(1)	(1)	(24)	(4)
Earnings from continuing operations before income taxes	10,767	13,847	33,448	31,831
Income tax (provision)	(3,797)	(5,510)	(12,109)	(11,947)
Earnings from continuing operations	6,970	8,337	21,339	19,884
Earnings (loss) from discontinued operations net of tax (provision) benefit of $(87), ($183), $(100) and $40, respectively	186	(74)	162	340
Net earnings	$ 7,156	$ 8,263	$ 21,501	$ 20,224
EARNINGS (LOSS) PER SHARE:
From continuing operations (in dollars per share)	$ 1.65	$ 1.98	$ 5.06	$ 4.71
From discontinued operations (in dollars per share)	$ 0.05	$ (0.02)	$ 0.04	$ 0.08
Basic and diluted net earnings per common share (in dollars per share)	$ 1.70	$ 1.96	$ 5.10	$ 4.79
DIVIDENDS PER COMMON SHARE (in dollars per share)	$ 0.22	$ 0	$ 0.44	$ 0

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Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2013

Summary of Significant Accounting Policies [Abstract]

Nature of Operations and Principles of Consolidation

Nature of Operations and Principles of Consolidation

The Company is engaged in the business of crude oil and natural gas 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 unaudited 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 intercompany accounts and transactions.

Cash and Cash Equivalents

Cash and Cash Equivalents

Cash and cash equivalents include any Treasury bill, commercial paper, money market fund or federal funds with maturity of 90 days or less.  Depending on cash availability and market conditions, investments in corporate and municipal bonds, which are classified as investments in marketable securities, may also be made from time to time.  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.

Inventory

Inventory

Inventory consists of crude oil held in storage tanks and at third-party pipelines as part of the Company’s crude oil marketing operations.  Crude oil inventory is carried at the lower of average cost or market.

Prepayments

Prepayments

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

	September 30,		December 31,
	2013		2012
Cash collateral deposits for commodity purchases	$	5,000	$	5,000
Insurance premiums		2,753		1,872
Commodity imbalances and futures		11		353
Rents, license and other		820		867
	$	8,584	$	8,092

Property and Equipment

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 is removed from the accounts and any gain or loss is reflected in earnings.

At various times during 2012, the Company sold certain used trucks and equipment from its transportation and marketing truck fleets and recorded pre-tax gains totaling $4,364,000.  Such sales were substantially reduced during 2013.

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, 2013, the Company had no unevaluated or suspended exploratory drilling costs.

Depreciation, depletion and amortization of the cost of proved oil and gas properties are 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 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 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 are then discounted using a market based 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, 2013 and 2012, there were $216,000 and $90,000, respectively, of impairment provisions on producing oil and gas properties.  Such impairment provisions were $74,000 and $19,000 for the three-month periods ended September 30, 2013.

On a quarterly basis, management evaluates the carrying value of non-producing oil and gas leasehold properties and may deem them impaired based on remaining lease term, area drilling activity and the Company’s plans for the property.  This fair value measure depends highly on management’s assessment of the likelihood of continued exploration efforts in a given area and, as such, data inputs are categorized as unobservable or Level 3 inputs.  Importantly, this fair value measure only applies to the write-down of capitalized costs and will never result in an increase to reported earnings. Accordingly, impairment provisions on non-producing properties totaling $198,000 and $788,000 were recorded for the nine-month periods ended September 30, 2013 and 2012, respectively.  Such impairment provisions were $98,000 and $230,000 for the three-month periods ended September 30, 2013.  Capitalized costs for non-producing oil and gas leasehold interests currently represent approximately four percent of total oil and gas property costs and are categorized as follows (in thousands):

	September 30,		December 31,
	2013		2012
South Texas Project acreage	$	3,669	$	3,263
West Texas Project acreage		129		180
Napoleonville, Louisiana acreage		162		323
Other acreage areas		398		329
Total Non-producing Leasehold Costs	$	4,358	$	4,095

The South Texas, West Texas and Napoleonville acreage areas have active or scheduled drilling operations underway and holding the underlying acreage is essential to the ongoing exploration effort.  The ‟other acreage areas” category consists of smaller onshore interests dispersed over a wide geographical area.  Since the Company is generally not the operator of its oil and gas property interest, it does not maintain the underlying detail acreage data and the Company is dependent on the operator when determining which specific acreage will ultimately be drilled.  However, the capitalized cost detail on a property-by-property basis is reviewed by management, and deemed impaired if development is not anticipated prior to lease expiration.  Onshore leasehold periods are normally three years and may contain renewal options.  Capitalized cost activity on the ‟other acreage areas” was as follows (in thousands):

	Leasehold
	Costs
Balance December 31, 2012	$	329
Property additions		267
Impairments		(198	)
Balance September 30, 2013	$	398

Cash Deposits and Other Assets

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.  Insurance collateral deposits are invested at the discretion of the Company’s insurance carrier and such investments primarily consist of intermediate term federal government bonds and bonds backed by federal agencies.  Components of cash deposits and other assets are as follows (in thousands):

	September 30,		December 31,
	2013		2012
Insurance collateral deposits	$	3,084	$	3,413
State collateral deposits		166		170
Materials and supplies		591		616
	$	3,841	$	4,199

Revenue Recognition

Revenue Recognition

Certain 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 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.

Most crude oil purchase contracts and sale contracts qualify and are designated as non-trading activities and the Company considers such contracts as normal purchases and sales activity.  For normal purchases and sales, 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, 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 unaudited condensed consolidated financial statements.  Reporting such crude oil contracts on a gross revenue basis would increase the Company’s reported revenues by $1,176,156,000 and $714,489,000 for the nine months ended September 30, 2013 and 2012, respectively.

Transportation segment 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

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 95 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

Letter of Credit Facility

The Company maintains a Credit and Security Agreement with Wells Fargo Bank to provide a $60 million stand-by letter of credit facility that is used 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 and certain marketing and transportation equipment.  Stand-by letters of credit issued totaled $15.4 million and $21.9 million as of September 30, 2013 and December 31, 2012, respectively.  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.  The Company is currently in compliance with all such financial covenants.

Statement of Cash Flows

Statement of Cash Flows

Interest paid totaled $24,000 and $4,000 during the nine-month periods ended September 30, 2013 and 2012, respectively, while taxes paid during these same periods totaled $9,863,000 and $6,636,000, respectively.  Non-cash investing activities for property and equipment were $1,454,000 and $2,419,000 as of September 30, 2013 and December 31, 2012, respectively and $2,962,000 and $4,070,000 as of September 30, 2012 and December 31, 2011, respectively.  There were no significant non-cash financing activities in any of the periods reported.

Earnings Per Share

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 presented herein. The weighted average number of shares outstanding was 4,217,596 for 2013 and 2012.  There were no potentially dilutive securities during those periods.

Share-Based Payments

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

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 oil and gas reserve volumes forming the foundation for calculating depreciation, depletion and amortization and for estimating cash flows when assessing impairment triggers and when estimating values associated with oil and gas properties.  Other examples include revenue accruals, the provision for bad debts, insurance related accruals, income tax permanent and timing differences, contingencies and valuation of fair value contracts.

Income Taxes

Income Taxes

Income taxes are accounted for using the asset and liability method.  Under this approach, deferred tax assets and liabilities are recognized based on anticipated future tax consequences attributable to differences between financial statement carrying amounts of assets and liabilities and their respective tax basis.

Use of Derivative Instruments

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.  Certain of 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.  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, 2013 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	$	555	$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-		-		(39	)		-
Less Counterparty Offsets		-		-		-			-
As Reported Fair Value Contracts	$	555	$	-	$	(39	)	$	-

As of September 30, 2013, one 100,000 barrel crude oil commodity put option and one commodity purchase and sale contract comprised the Company’s derivative valuations.  The purchase and sale contract encompasses approximately 175 barrels of crude oil per day in each of October, November and December 2013 and January and February 2014, respectively.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Balance Sheet as of December 31, 2012 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	$	688		$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-			-		682			-
Less Counterparty Offsets		(270	)		-		(270	)		-
As Reported Fair Value Contracts	$	418		$	-	$	412		$	-

As of December 31, 2012, twenty-four commodity purchase and sales contracts comprise all of the Company’s derivative valuations.  Such contracts encompass the purchase and sale of approximately 900 barrels of crude oil per day and 172,000 mmbtu of natural gas per day during January 2013 with crude oil volumes continuing at the rate of 200 barrels per day through June 2013 together with natural gas volumes of 1,000 mmbtu and 41,000 mmbtu per day in February 2013 and March 2013, respectively.

The Company only enters into commodity contracts with credit worthy counterparties or obtains collateral support for such activities.  As of September 30, 2013 and December 31, 2012, 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.  The Company has no other financial investment arrangements that would serve to offset its derivative contracts.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Statement of Operations for the nine months ended September 30, 2013 and 2012 as follows (in thousands):

	Earnings (Loss)						Earnings (Loss)
	Nine Months Ended						Three Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Revenues – marketing	$	(105	)	$	(2,555	)	$	(103	)	$	(1,562	)

Fair Value Measurements

Fair Value Measurements

The carrying amount reported in the balance sheet for cash and cash equivalents, accounts receivable and accounts payable approximates fair value because of the immediate or short-term maturity of these financial instruments.  Marketable securities are recorded at fair value based on market quotations from actively traded liquid markets.

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.  For Level 1 valuation of marketable securities, the Company utilizes market quotations provided by its primary financial institution and for the valuation of derivative financial instruments the Company utilizes the New York Mercantile Exchange (NYMEX) for such 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 NYMEX, the 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, 2013, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets		Total
Derivatives
- Current assets	$	-	$	555		$	-	$	-	$	555
- Current liabilities		-		(39	)		-		-		(39	)
Net Value	$	-	$	516		$	-	$	-	$	516

As of December 31, 2012, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets			Total
Derivatives
- Current assets	$	299	$	389		$	-	$	(270	)	$	418
- Current liabilities		-		(682	)		-		270			(412	)
Net Value	$	299	$	(293	)	$	-	$	-		$	6

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, 2013 and December 31, 2012, 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 are included in their entirety in the fair value hierarchy.

Recent Accounting Pronouncement

Recent Accounting Pronouncement

In December 2011, the Financial Accounting Standards Board (“FASB”) issued ASU 2011-11.  This update requires additional disclosures about an entity’s right of setoff and related arrangements associated with its financial and derivative instruments.  The ASU requires a tabular presentation that reflects the gross, net and setoff amounts associated with such assets and liabilities among other requirements.  The Company adopted ASU 2011-11 effective January 1, 2013 and the adoption of ASU 2011-11 did not have a material impact on the Company’s consolidated financial statements, but additional disclosures regarding fair value measurements resulted.

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.

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Summary of Significant Accounting Policies (Details) (USD $)	9 Months Ended		12 Months Ended												9 Months Ended		12 Months Ended						9 Months Ended		9 Months Ended							3 Months Ended			9 Months Ended		3 Months Ended		9 Months Ended								9 Months Ended		3 Months Ended
	Sep. 30, 2013 mi	Sep. 30, 2012	Dec. 31, 2012	Dec. 31, 2011	Sep. 30, 2013 Commodity Contract [Member] Contract	Dec. 31, 2012 Commodity Contract [Member] Contract	Sep. 30, 2013 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Current Assets [Member]	Dec. 31, 2012 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Current Assets [Member]	Sep. 30, 2013 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Other Assets [Member]	Dec. 31, 2012 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Other Assets [Member]	Sep. 30, 2013 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Current Liabilities [Member]	Dec. 31, 2012 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Current Liabilities [Member]	Sep. 30, 2013 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Other Liabilities [Member]	Dec. 31, 2012 Commodity Contract [Member] Not Designated as Hedging Instrument [Member] Other Liabilities [Member]	Sep. 30, 2013 Commodity Contract [Member] Oct 2013 to Dec 2013 [Member] bbl	Sep. 30, 2013 Commodity Contract [Member] Jan 2014 to Feb 2014 [Member] bbl	Dec. 31, 2012 Commodity Contract [Member] Jan 2013 [Member] bbl	Dec. 31, 2012 Commodity Contract [Member] Jan 2013 [Member] MMBTU	Dec. 31, 2012 Commodity Contract [Member] Feb 2013 to June 2013 [Member] bbl	Dec. 31, 2012 Commodity Contract [Member] Feb 2013 [Member] MMBTU	Dec. 31, 2012 Commodity Contract [Member] Mar 2013 [Member] MMBTU	Sep. 30, 2013 Commodity Put Option [Member] bbl Contract	Sep. 30, 2013 Wells Fargo Bank [Member]	Dec. 31, 2012 Wells Fargo Bank [Member]	Sep. 30, 2013 Revenue [Member]	Sep. 30, 2013 Revenue [Member] Customer Concentration Risk [Member]	Sep. 30, 2013 Accounts Receivable [Member]	Sep. 30, 2013 Accounts Receivable [Member] Product Concentration Risk [Member]	Sep. 30, 2013 Minimum [Member]	Sep. 30, 2013 Minimum [Member] Customer Concentration Risk [Member] Customer	Sep. 30, 2013 Maximum [Member]	Sep. 30, 2013 Maximum [Member] Customer Concentration Risk [Member] Customer	Sep. 30, 2013 Producing Oil and Gas Properties [Member]	Sep. 30, 2012 Producing Oil and Gas Properties [Member]	Sep. 30, 2013 Producing Oil and Gas Properties [Member]	Sep. 30, 2012 Producing Oil and Gas Properties [Member]	Sep. 30, 2013 Non-Producing Oil and Gas Properties [Member]	Sep. 30, 2012 Non-Producing Oil and Gas Properties [Member]	Sep. 30, 2013 Non-Producing Oil and Gas Properties [Member]	Sep. 30, 2012 Non-Producing Oil and Gas Properties [Member]	Sep. 30, 2013 South Texas Project acreage [Member]	Dec. 31, 2012 South Texas Project acreage [Member]	Sep. 30, 2013 West Texas Project acreage [Member]	Dec. 31, 2012 West Texas Project acreage [Member]	Sep. 30, 2013 Napoleonville, Louisiana acreage [Member]	Dec. 31, 2012 Napoleonville, Louisiana acreage [Member]	Sep. 30, 2013 Other acreage areas [Member]	Dec. 31, 2012 Other acreage areas [Member]	Sep. 30, 2013 Onshore leasehold [Member]
Nature of Operations and Principles of Consolidation [Abstract]
Primary area of operation (in miles)	1,000
Components of prepayments and other [Abstract]
Cash collateral deposits for commodity purchases	$ 5,000,000		$ 5,000,000
Insurance premiums	2,753,000		1,872,000
Commodity imbalances and futures	11,000		353,000
Rents, license and other	820,000		867,000
Prepayments, total	8,584,000		8,092,000
Property, Plant and Equipment [Line Items]
Gain on sale of assets			4,364,000
Property and equipment, useful life																													3 years		20 years																		3 years
Capitalized costs for non producing oil and gas leasehold interests specified as percentage of total costs (in hundredths)																																					4.00%		4.00%
Total Non-producing Leasehold Costs	4,358,000		4,095,000																																						3,669,000	3,263,000	129,000	180,000	162,000	323,000	398,000	329,000
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Balance December 31, 2012																																															329,000
Property additions																																															267,000
Impairment	(414,000)	(878,000)																															(74,000)	(19,000)	(216,000)	(90,000)	(98,000)	(230,000)	(198,000)	(788,000)							(198,000)
Balance June 30, 2013																																															398,000
Cash Deposits and Other Assets [Abstract]
Insurance collateral deposits	3,084,000		3,413,000
State collateral deposits	166,000		170,000
Materials and supplies	591,000		616,000
Cash deposits and other	3,841,000		4,199,000
Revenue Recognition [Abstract]
Increase in the entity's reported revenue	1,176,156,000	714,489,000
Concentration of Credit Risk [Line Items]
Concentration risk, percentage (in hundredths)																										50.00%		95.00%
Concentration risk, additional characteristic																										Large crude oil refining concerns		Crude oil and natural gas marketing activities
Number of customers																														2		3
Maximum percentage of US demand supplied by company (in hundredths)	1.00%
Percentage of revenues from one customer which loss would not have material effect (in hundredths)																									10.00%
Industry practice payment of receivables																											25 days
Letter of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity																							60,000,000
Standby letters of credit issued																							15,400,000	21,900,000
Covenant terms																							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. The Company is currently in compliance with all such financial covenants.
Current ratio																							1.1
Statement of Cash Flows [Abstract]
Interest paid	24,000	4,000
Income taxes paid	9,863,000	6,636,000
Non-cash investing activities for property and equipment	1,454,000	2,962,000	2,419,000	4,070,000
Earnings Per Share [Abstract]
Weighted average number of shares outstanding (in shares)	4,217,596		4,217,596
Fair Value Forward Hydrocarbon Commodity Contracts at Gross Valuation [Abstract]
Asset Derivatives							555,000	688,000	0	0	0	0	0	0
Liability Derivatives							0	0	0	0	(39,000)	682,000	0	0
Less Counterparty Offsets							0	(270,000)	0	0	0	(270,000)	0	0
As Reported Fair Value Contracts							$ 555,000	$ 418,000	$ 0	$ 0	$ (39,000)	$ 412,000	$ 0	$ 0
Number of contracts held					1	24																1
Volume committed per day under commodity purchase and sale contract (in barrels or mmbtu)															175	175	900	172,000	200	41,000	1,000
Volume of crude oil committed under commodity put option (in barrels)																						100,000

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Discontinued Operation

9 Months Ended

Sep. 30, 2013

Discontinued Operation [Abstract]

Discontinued Operation

Note 6 – Discontinued Operation

On February 27, 2012, the Company completed the sale of contracts, inventory and certain equipment associated with the refined products segment of its marketing business.  Revenues from this segment included in net earnings from discontinued operations totaled $25,633,000 for the three-month period ended March 31, 2012.  The Company received $2 million in cash proceeds plus a cash payment of $1,546,000 for the agreed value of refined product inventories on the date of sale.  The net gain recognized upon this sale totaled $1,622,000.  The Company conducted an orderly wind-down of the operation which primarily consisted of collecting outstanding accounts receivable and satisfying all existing obligations.  The Company’s fee interest in certain parcels of real estate was retained and the estimated fair value of such properties exceeded the Company’s cost basis in the properties.  Therefore, an impairment assessment of long-lived assets was not necessary.  The proceeds secured from this transaction exceeded the sum of carrying costs of the assets sold plus severance and other wind-down costs and as a result, the first quarter 2012 pre-tax earnings from this former segment totaled $808,000.  Retained accounts receivable and payable obligations were substantially collected or satisfied as of the date of this report.

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Basis of Presentation

9 Months Ended

Sep. 30, 2013

Basis of Presentation [Abstract]

Basis of Presentation

Note 1 - Basis of Presentation

The accompanying unaudited condensed consolidated financial statements, 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, 2013, its results of operations for the nine months ended September 30, 2013 and 2012 and its cash flows for the nine months ended September 30, 2013 and 2012. Certain information and note disclosures normally included in annual financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted pursuant to Securities and Exchange Commission rules and regulations.  The impact on the accompanying financial statements of events occurring after September 30, 2013, has been evaluated through the date these financial statements were issued.

Although the Company believes the disclosures made are adequate to make the information presented not misleading, it is suggested that these unaudited 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.

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Transactions with Affiliates (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Chairman and Chief Executive Officer, and Certain Family Partnerships and Affiliates [Member]
Related Party Transaction [Line Items]
Investment commitments with related party	$ 10,400,000	$ 18,300,000
Due to related parties, current	48,000		42,000
Expense reimbursements from related parties	119,000	113,000
Other Affiliated Entities [Member]
Related Party Transaction [Line Items]
Expense reimbursements from related parties	54,000	52,000
Expense reimbursements to related parties	75,000	73,000
Estimated annual rental expense	480,000
Lease term	7 years
Rent expense paid	$ 360,000	$ 322,000

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Segment Reporting (Tables)

9 Months Ended

Sep. 30, 2013

Segment Reporting [Abstract]

Information concerning business activities and assets by segment

The Company is engaged in the business of crude oil and natural gas 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, 2013
Marketing
- Crude Oil	$	2,915,056	$	35,509		$	5,517	$	9,512
- Natural gas		2,272		(111	)		147		-
Marketing Total		2,917,328		35,398			5,664		9,512
Transportation		51,795		4,479			5,263		3,162
Oil and gas		11,022		996			5,367		10,459
	$	2,980,145	$	40,873		$	16,294	$	23,133
Period Ended September 30, 2012
Marketing
- Crude Oil	$	2,438,815	$	29,880		$	4,324	$	9,079
- Natural gas		4,069		1,057			16		-
Marketing Total		2,442,884		30,937			4,340		9,079
Transportation		50,137		7,919			4,186		15,484
Oil and gas		11,467		159			6,113		18,566
	$	2,504,488	$	39,015		$	14,639	$	43,129

- Three Month Comparison

			Segment			Depreciation		Property and
			Operating			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended September 30, 2013
Marketing
- Crude Oil	$	1,039,337	$	11,394		$	1,939	$	932
- Natural gas		430		(124	)		-		-
Marketing Total		1,039,767		11,270			1,939		932
Transportation		16,906		1,248			1,787		1,589
Oil and gas		4,097		752			1,647		4,314
	$	1,060,770	$	13,270		$	5,373	$	6,835
Period Ended September 30, 2012
Marketing
- Crude Oil	$	773,611	$	13,278		$	1,596	$	1,673
- Natural gas		1,121		174			15		-
Marketing Total		774,732		13,452			1,611		1,673
Transportation		16,741		2,607			1,574		4,740
Oil and gas		4,052		314			2,265		5,106
	$	795,525	$	16,373		$	5,450	$	11,519

Reconciliation of segment earnings to earnings before income taxes

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

	Nine Months Ended						Three Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Segment operating earnings (loss)	$	40,873		$	39,015		$	13,270		$	16,373
- General and administrative		(7,504	)		(7,300	)		(2,535	)		(2,603	)
Operating earnings		33,369			31,715			10,735			13,770
- Interest income		103			120			33			78
- Interest expense		(24	)		(4	)		(1	)		(1	)
Earnings from continuing operations
before income taxes and
discontinued operations	$	33,448		$	31,831		$	10,767		$	13,847

Identifiable assets by industry segment

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

	September 30,		December 31,
	2013		2012
Marketing
- Crude oil	$	329,893	$	277,920
- Natural gas		8,496		11,764
Marketing Total		338,389		289,684
Transportation		37,019		38,940
Oil and gas		38,962		35,788
Other		60,310		55,089
	$	474,680	$	419,501

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Commitments and Contingencies (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Commitments and Contingencies [Abstract]
Estimated expenses and related liabilities for losses incurred not reported to insurance carrier	$ 966,000	$ 1,545,000
Accrued medical claims	973,000	506,000
Minimum annual individual medical claims for stop loss coverage	100,000
Umbrella insurance coverage	2,000,000
Minimum aggregate medical claims for umbrella insurance coverage for 2013	$ 4,500,000

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Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 05, 2013
Document and Entity Information [Abstract]
Entity Registrant Name	ADAMS RESOURCES & ENERGY, INC.
Entity Central Index Key	0000002178
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		4,217,596
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2013

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Discontinued Operation (Details) (Refined products segment [Member], USD $)	3 Months Ended	12 Months Ended
	Mar. 31, 2012	Dec. 31, 2012
Refined products segment [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues from discontinued operations	$ 25,633,000
Proceeds from sale of contracts and certain equipment		2,000,000
Proceeds from sale of inventory		1,546,000
Gain (loss) on disposal of discontinued operation		1,622,000
Pre-tax earnings from discontinued operation	$ 808,000