Adams Resources & Energy (AE) 10-K 13 Mar 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Mar. 01, 2015	Jun. 30, 2014
Document and Entity Information [Abstract]
Entity Registrant Name	ADAMS RESOURCES & ENERGY, INC.
Entity Central Index Key	2178
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Public Float			$172,042,728
Entity Common Stock, Shares Outstanding		4,217,596
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
CURRENT ASSETS:
Cash and cash equivalents	$80,184	$60,733
Accounts receivable, net of allowance for doubtful accounts of $179 and $252, respectively	144,434	243,930
Inventories	13,481	27,616
Fair value contracts	936	395
Income tax receivable	970	2,097
Prepayments	10,940	16,779
Current assets of discontinued operations	0	180
Total current assets	250,945	351,730
PROPERTY AND EQUIPMENT:
Marketing	65,865	52,996
Transportation	63,239	59,185
Oil and gas (successful efforts method)	88,661	98,947
Other	186	1,305
Property and equipment	217,951	212,433
Less - Accumulated depreciation, depletion and amortization	-133,080	-120,568
Net property and equipment	84,871	91,865
OTHER ASSETS:
Cash deposits and other	4,998	4,487
Total Assets	340,814	448,082
CURRENT LIABILITIES:
Accounts payable	160,743	266,099
Accounts payable - related party	51	38
Fair value contracts	943	0
Accrued and other liabilities	6,208	5,583
Current deferred income taxes	658	358
Current liabilities of discontinued operations	0	91
Total current liabilities	168,603	272,169
LONG-TERM DEBT	0	0
OTHER LIABILITIES:
Asset retirement obligations	2,464	2,564
Deferred taxes and other liabilities	12,250	18,664
Total liabilities	183,317	293,397
COMMITMENTS AND CONTINGENCIES (NOTE 6)
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 issued and outstanding	422	422
Contributed capital	11,693	11,693
Retained earnings	145,382	142,570
Total shareholders' equity	157,497	154,685
Liabilities and shareholders' equity	$340,814	$448,082

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified
CURRENT ASSETS:
Allowance for doubtful accounts	$179	$252
SHAREHOLDERS' EQUITY:
Preferred stock - par value (in dollars per share)	$1	$1
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 issued (in shares)	4,217,596	4,217,596
Common stock - shares outstanding (in shares)	4,217,596	4,217,596

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
REVENUES:
Marketing	$4,050,497	$3,863,057	$3,292,948
Transportation	68,968	68,783	67,183
Oil and natural gas	13,361	14,129	15,954
Total revenues	4,132,826	3,945,969	3,376,085
COSTS AND EXPENSES:
Marketing	4,020,017	3,815,006	3,240,858
Transportation	56,802	56,504	51,009
Oil and natural gas operations	15,826	8,748	12,941
Oil and natural gas property sale (gain)	-2,528	0	-2,203
General and administrative	8,613	9,060	8,810
Depreciation, depletion and amortization	24,615	22,275	20,714
Total costs and expenses	4,123,345	3,911,593	3,332,129
Operating Earnings	9,481	34,376	43,956
Other Income (Expense):
Interest income	301	198	190
Interest expense	-2	-24	-10
Earnings from continuing operations before income taxes	9,780	34,550	44,136
Income Tax (Provision) Benefit:
Current	-9,712	-9,269	-11,286
Deferred	6,151	-3,160	-5,378
Income tax (provision) benefit	-3,561	-12,429	-16,664
Earnings from continuing operations	6,219	22,121	27,472
Earnings (loss) from discontinued operations net of tax (provision) benefit of $(163), $275 and $(172) respectively	304	-511	319
Net Earnings	$6,523	$21,610	$27,791
EARNINGS PER SHARE:
From continuing operations (in dollars per share)	$1.48	$5.24	$6.51
From discontinued operations (in dollars per share)	$0.07	($0.12)	$0.08
Basic and diluted net earnings per share (in dollars per share)	$1.55	$5.12	$6.59
Dividends declared per common share (in dollars per share)	$0.88	$0.66	$0.62

CONSOLIDATED_STATEMENTS_OF_OPE1

CONSOLIDATED STATEMENTS OF OPERATIONS (Parenthetical) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CONSOLIDATED STATEMENTS OF OPERATIONS [Abstract]
Earnings (loss) from discontinued operations, tax	($163)	$275	($172)

CONSOLIDATED_STATEMENTS_OF_SHA

CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (USD $)	Common Stock [Member]	Contributed Capital [Member]	Retained Earnings [Member]	Total
In Thousands, unless otherwise specified
BALANCE at Dec. 31, 2011	$422	$11,693	$98,567	$110,682
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings	0	0	27,791	27,791
Dividends paid on common stock	0	0	-2,615	-2,615
BALANCE at Dec. 31, 2012	422	11,693	123,743	135,858
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings	0	0	21,610	21,610
Dividends paid on common stock	0	0	-2,783	-2,783
BALANCE at Dec. 31, 2013	422	11,693	142,570	154,685
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings	0	0	6,523	6,523
Dividends paid on common stock	0	0	-3,711	-3,711
BALANCE at Dec. 31, 2014	$422	$11,693	$145,382	$157,497

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CASH PROVIDED BY OPERATIONS:
Net earnings	$6,523	$21,610	$27,791
Adjustments to reconcile net earnings to net cash from operating activities -
Depreciation, depletion and amortization	24,615	22,275	20,714
Property sales (gains) oil and gas	-2,528	0	-2,203
Property sale (gains) other	-1,028	-683	-4,095
Dry hole costs incurred	1,034	233	43
Impairment of oil and natural gas properties	8,009	2,630	5,555
Provision for doubtful accounts	-73	46	-51
Deferred income taxes	-6,151	3,161	5,378
Net change in fair value contracts	402	-389	1,377
Decrease (increase) in accounts receivable	99,749	-4,770	-4,820
Decrease (increase) in inventories	14,135	606	-9,579
Decrease (increase) in income tax receivable	1,127	-898	-719
Decrease (increase) in prepayments	5,839	-8,687	2,559
Increase (decrease) in accounts payable	-104,887	7,809	10,474
Increase (decrease) in accrued and other liabilities	448	-516	1,227
Other changes, net	-81	1,549	843
Net cash provided by operating activities	47,133	43,976	54,494
INVESTING ACTIVITIES:
Property and equipment additions	-30,523	-27,602	-51,012
Insurance and state collateral (deposits) refunds	-493	-1,179	-582
Proceeds from property sales	7,045	1,082	6,342
Proceeds from the sale of discontinued operations	0	0	3,546
Net cash (used in) investing activities	-23,971	-27,699	-41,706
FINANCING ACTIVITIES:
Dividend payments	-3,711	-2,783	-2,615
Net cash (used in) financing activities	-3,711	-2,783	-2,615
Increase (decrease) in cash and cash equivalents	19,451	13,494	10,173
Cash and cash equivalents at beginning of year	60,733	47,239	37,066
Cash and cash equivalents at end of year	$80,184	$60,733	$47,239

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Summary of Significant Accounting Policies [Abstract]
Summary of Significant Accounting Policies	(1)	Summary of Significant Accounting Policies
	Principles of Consolidation
	The accompanying consolidated financial statements include the accounts of Adams Resources & Energy, Inc., a Delaware corporation (‟ARE”) together with its wholly owned subsidiaries (the ‟Company”) after elimination of all intercompany accounts and transactions.  The impact on the accompanying financial statements of events occurring after December 31, 2014 was evaluated through the date of issuance of these financial statements.
	Nature of Operations
	The Company is engaged in the business of crude oil marketing, 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.
	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.
	Marketable Securities
	From time to time, the Company may invest in marketable securities consisting of investment grade corporate bonds traded in liquid markets.  Such bonds are held for the purpose of investing in liquid funds and are not generally intended to be retained on a long term basis.  Marketable securities are initially recognized at acquisition costs inclusive of transaction costs and are classified as trading securities.  In subsequent periods, marketable securities are valued at fair value.  Changes in these fair values are recognized as gains or losses in the accompanying statement of operations under the caption ‟Costs and Expenses – Marketing”.  Interest on marketable securities is recognized directly in the statement of operations during the period earned.
	Allowance for Doubtful Accounts
	Accounts receivable are the product of sales of crude oil and natural gas and the sale of trucking services.  Marketing segment wholesale level sales of crude oil comprise in excess of 90 percent of total accounts receivable and under industry practices, such items are ‟settled” and paid in cash within 20 days of the month following the transaction date.  For such receivables, an allowance for doubtful accounts is determined based on specific account identification.  The balance of accounts receivable results primarily from the sale of trucking services.  For this component of receivables, the allowance for doubtful accounts is determined based on a review of specific accounts combined with a review of the general status of the aging of all accounts.
	Inventories
	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.  Due to declining crude oil prices, for the years ended December 31, 2014 and 2013 the Company recorded inventory liquidation and valuation losses totaling $14,247,000 and $3,824,000, respectively.
	Prepayments
	The components of prepayments and other are as follows (in thousands):
			December 31,
			2014			2013
	Cash collateral deposits for commodity purchases		$	7,872		$	13,705
	Insurance premiums			2,316			2,490
	Rents, license and other			752			584
			$	10,940		$	16,779
	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.
	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 December 31, 2014 and 2013, the Company had no unevaluated or suspended exploratory drilling costs.
	Depreciation, depletion and amortization of the cost of proved oil and gas properties is calculated using the unit-of-production method.  The reserve base used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves.  For lease and well equipment, development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves.  All other property and equipment is depreciated using the straight-line method over the estimated average useful lives of three to twenty years.
	The Company 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 and 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 years ended December 31, 2014, 2013 and 2012, there were $4,001,000, $1,373,000 and $4,699,000 respectively, of impairment provisions on producing oil and gas properties.
	Fair value measurements for producing oil and gas properties that were subject to fair value impairment for the years ended December 31, 2014 and 2013 summarized as follows (in thousands):
			Producing Properties
			Subject to Fair
			Value Impairment
			2014			2013
	Net book value at January 1		$	10,180		$	13,180
	Property additions			469			5,661
	Depletion taken			(1,792	)		(3,727	)
	Impairment valuation loss			(4,001	)		(1,373	)
	Net book value at December 31		$	4,856		$	13,741
	Fair value measurements for producing oil and gas properties are based on Level 3 – Significant Unobservable Inputs – (see “Fair Value Measurements” below).
	On a quarterly basis, management 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 $4,008,000, $1,257,000 and $856,000 were recorded for the years ending December 31, 2014, 2013 and 2012, respectively.  Capitalized costs for non-producing oil and gas leasehold interests currently represent approximately four percent of remaining unamoritized oil and gas property carrying costs and categorize as follows (in thousands):
			December 31,			December 31,
			2014			2013
	South Texas Project acreage		$	357		$	4,217
	West Texas Project			-			116
	Napoleonville Louisiana acreage			48			162
	Other acreage areas			554			411
	Total Non-producing Leasehold Costs		$	959		$	4,906
	The South 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 interests, it does not maintain underlying detail acreage data and 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
			2014			2013
	Net book value January 1		$	411		$	329
	Property additions			580			304
	Property sale			-			-
	Impairments			(437	)		(222	)
	Net book value December 31		$	554		$	411
	During 2014, the Company sold substantially all of its producing property interests in Oklahoma.  Proceeds totaled $1,731,000 and the Company recorded a $1,149,000 pre-tax gain from this sale.  Also during 2014 the Company sold one-half of its interest in sections of its South Texas project interest.  Proceeds totaled $1,509,000 and the Company recorded a $632,000 pre-tax gain from this sale.  Certain other oil and gas property interests were also sold in 2014 for proceeds totaling $822,000 and gains totaling $747,000.  During 2012, the Company sold half of its interest in certain non-producing Kansas oil and gas properties.  Proceeds from the sale totaled $578,000 and the Company recorded a $475,000 pre-tax gain from this sale.  Also during 2012, the Company sold its interest in two oil and gas producing property units for total proceeds of $3,049,000.  The Company realized a $1,728,000 pre-tax gain from these two sales.
	During 2014, 2013 and 2012, the Company sold certain used trucks and equipment from its marketing and transportation segments and recorded net pre-tax gains totaling $1,028,000, $683,000 and $2,482,000, respectively.
	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):
			December 31,
			2014			2013
	Insurance collateral deposits		$	4,536		$	3,718
	State collateral deposits			155			160
	Materials and supplies			307			609
			$	4,998		$	4,487
	Revenue Recognition
Commodity purchase and sale contracts utilized by the Company’s marketing business generally qualify as derivative instruments with certain specifically identified crude oil contracts 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 consolidated financial statements.
Most all crude oil purchase 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 consolidated financial statements.  Reporting such crude oil contracts on a gross revenue basis would increase the Company’s reported revenues by $1,272,034,000, $1,602,626,000 and $1,381,352,000 for the years ended December 31, 2014, 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.
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 purchases within the marketing segment.  This facility is collateralized by the eligible accounts receivable within the segment and certain marketing and transportation equipment.  Stand-by letters of credit issued totaled $15.3 million and $14.6 million as of December 31, 2014 and 2013, 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. subsidiary.  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 $2,000, $24,000 and $10,000 during the years ended December 31, 2014, 2013 and 2012, respectively.  Federal and state income taxes paid during these same periods totaled $8,169,000, $9,949,000, and $12,650,000, respectively.  In addition, State income tax refunds totaled $18,615, $4,000 and $10,000 in 2014, 2013 and 2012, respectively.  Non-cash investing activities for property and equipment items included in accounts payable as of period end were $1,137,000, $1,507,000 and $2,419,000 as of December 31, 2014, 2013 and 2012, respectively.  There were no significant non-cash financing activities in any of the periods reported.
Earnings per Share
Earnings per share are based on the weighted average number of shares of common stock and potentially dilutive common stock shares outstanding during the period. The weighted average number of shares outstanding was 4,217,596 for 2014, 2013 and 2012.  There were no potentially dilutive securities outstanding during those periods.
Share-Based Payments
During the periods presented herein, the Company had no stock-based employee compensation plans, nor any other share-based payment arrangements.
Use of Estimates
The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates. Examples of significant estimates used in the accompanying consolidated financial statements include the oil and gas reserve volumes that form the foundation for calculating depreciation, depletion and amortization and estimating cash flows to assess impairment triggers and estimated 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 (See also Note (2).
Use of Derivative Instruments
The Company’s marketing segment is involved in the purchase and sale of crude oil.  The Company seeks to make a profit by procuring this commodity as it is produced and then delivering the material to end users or the 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.  Some 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 wholesale distribution businesses. None of the Company’s derivative instruments have been designated as hedging instruments.  The accounting methodology utilized by the Company for its commodity contracts is further discussed below under the caption ‟Fair Value Measurements”.
The estimated fair value of forward month commodity contracts (derivatives) is reflected in the accompanying Consolidated Balance Sheet as of December 31, 2014 as follows (in thousands):
		Balance Sheet Location and Amount
		Current			Other			Current			Other
		Assets			Assets			Liabilities			Liabilities
Asset Derivatives
- Fair Value Commodity
Contracts at Gross Valuation		$	1,332		$	-		$	-		$	-
Liability Derivatives
- Fair Value Commodity
Contracts at Gross Valuation			-			-			1,339			-
Less Counterparty Offsets			(396	)		-			(396	)		-
As Reported Fair Value Contracts		$	936		$	-		$	943		$	-
As of December 31, 2014, three purchase and sale contracts comprised the Company’s derivative valuations.  The purchase and sale contracts encompass approximately 294 barrels of crude oil per day in each of January and February 2015 and 129 barrels of crude oil per day in March through December 2015.
The estimated fair value of forward month commodity contracts (derivatives) is reflected in the accompanying Consolidated Balance Sheet as of December 31, 2013 as follows (in thousands):
		Balance Sheet Location and Amount
		Current			Other			Current			Other
		Assets			Assets			Liabilities			Liabilities
Asset Derivatives
- Fair Value Commodity
Contracts at Gross Valuation		$	449		$	-		$	-		$	-
Liability Derivatives
- Fair Value Commodity
Contracts at Gross Valuation			-			-			54			-
Less Counterparty Offsets			(54	)		-			(54	)		-
As Reported Fair Value Contracts		$	395		$	-		$	-		$	-
As of December 31, 2013, one 100,000 barrel crude oil commodity put option and one commodity purchase and sales contract comprised the Company’s derivative valuations.  The purchase and sale contract encompassed 175 barrels of crude oil per day in each of January and February 2014.
The Company only enters into commodity contracts with creditworthy counterparties or obtains collateral support for such activities.  As of December 31, 2014 and 2013, the Company was not holding nor had it posted any collateral to support its forward month fair value derivative activity. The Company is not subject to any credit-risk related trigger events.  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 Consolidated Statement of Operations for the years ended December 31, 2014, 2013 and 2012 as follows (in thousands):
		Gain (Loss)
Location		2014			2013			2012
Revenues – marketing		$	312		$	(193	)	$	(1,365	)
Fair Value Measurements
The carrying amount reported in the Consolidated Balance Sheet for cash and cash equivalents, accounts receivable and accounts payable approximates fair value because of the immediate or short-term maturity of these financial instruments.  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 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 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 valuations 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, 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 December 31, 2014, 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		$	-		$	1,332		$	-		$	(396	)	$	936
- Current liabilities			-			(1,339	)		-			396			(943	)
Net Value		$	-		$	(7	)	$	-		$	-		$	(7	)
As of December 31, 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		$	-		$	449		$	-		$	(54	)	$	395
- Current liabilities			-			(54	)		-			54			-
Net Value		$	-		$	395		$	-		$	-		$	395
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 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 December 31, 2014 and 2013, credit valuation adjustments were not significant to the overall valuation of the Company’s fair value contracts.  As a result, fair value assets and liabilities are included in their entirety in the fair value hierarchy.
The following table illustrates the factors impacting the change in the net value of the Company’s fair value contracts for the year ended December 31, 2014 (in thousands):
		Level 1			Level 2
		Quoted Prices			Observable			Total
Net Fair Value January 1,		$	-		$	395		$	395
- Net realized (gains) losses			-			220			220
- Option gain			-			99			99
- Option collateral			-			(714	)		(714	)
- Net unrealized gains (losses)			-			(7	)		(7	)
Net Fair Value December 31,		$	-		$	(7	)	$	(7	)
The following table illustrates the factors impacting the change in the net value of the Company’s fair value contracts for the year ended December 31, 2013 (in thousands):
		Level 1			Level 2
		Quoted Prices			Observable			Total
Net Fair Value January 1,		$	-		$	(27	)	$	(27	)
- Net realized (gains) losses			-			27			27
- Option deposit			-			615			615
- Net unrealized gains (losses)			-			(220	)		(220	)
Net Fair Value December 31,		$	-		$	395		$	395
Asset Retirement Obligations
The Company records a liability for the estimated retirement costs associated with certain tangible long-lived assets.  The estimated fair value of asset retirement obligations are recorded in the period in which they are incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the asset or the units of production associated with the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.  A summary of the Company’s asset retirement obligations is presented as follows (in thousands):
		2014			2013
Balance on January 1		$	2,564		$	1,886
-Liabilities incurred			111			431
-Accretion of discount			94			85
-Liabilities settled			(305	)		(138	)
-Revisions to estimates			-			300
Balance on December 31		$	2,464		$	2,564
In addition to an accrual for asset retirement obligations, the Company maintains $75,000 in escrow cash, which is legally restricted for the potential purpose of settling asset retirement costs in accordance with certain state regulations.  Such cash deposits are included in other assets in the accompanying consolidated balance sheet.
Recent Accounts Pronouncement
In April 2014, the Financial Accounting Standards Board (‟FASB”) issued updated guidance changing the criteria for reporting discontinued operations including enhanced disclosure requirements.  Under the new guidance, only activities representing a strategic shift in operations are presented as discontinued operations.  Such strategic shifts are those having a major effect on the organization’s operations and financial results.  The Company adopted the new guidance effective July 1, 2014 and the adoption did not have a material effect on the Consolidated Financial Statements.
In May 2014, the FASB amended the existing accounting standards for revenue recognition.  The amendments are based on the principle that revenue should be recognized to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.  The new guidance is effective for the annual period ending after December 15, 2016.  Early adoption is not permitted.  The amendments may be applied retrospectively to each prior period presented or retrospectively with the cumulative effect recognized as of the date of initial application.  Management is currently evaluating the impact of these amendments on the Company’s consolidated financial statements and the transition alternatives.
In August 2014, the FASB issued guidance requiring management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued.  The standard also provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements.  The new guidance is effective for the annual period ending after December 15, 2016, and interim periods thereafter, with early adoption permitted.  Management does not expect the adoption of this guidance to have an impact on the Consolidated Financial Statements.
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.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Taxes [Abstract]
Income Taxes	(2)  Income Taxes
	The following table shows the components of the Company’s income tax (provision) benefit (in thousands):
			Years ended December 31,
			2014			2013			2012
	Current:
	Federal		$	(8,626	)	$	(8,102	)	$	(10,282	)
	State			(1,249	)		(892	)		(1,176	)
				(9,875	)		(8,994	)		(11,458	)
	Deferred:
	Federal			5,878			(2,682	)		(4,940	)
	State			273			(478	)		(438	)
				6,151			(3,160	)		(5,378	)
			$	(3,724	)	$	(12,154	)	$	(16,836	)
	The following table summarizes the components of the income tax (provision) benefit (in thousands):
			Years ended December 31,
			2014			2013			2012
	From continuing operations		$	(3,561	)	$	(12,429	)	$	(16,664	)
	From discontinued operations			(163	)		275			(172	)
			$	(3,724	)	$	(12,154	)	$	(16,836	)
	Taxes computed at the corporate federal income tax rate reconcile to the reported income tax (provision) as follows (in thousands):
			Years ended December 31,
			2014			2013			2012
	Statutory federal income tax (provision) benefit		$	(3,587	)	$	(11,819	)	$	(15,619	)
	State income tax (provision) benefit			(634	)		(891	)		(1,049	)
	Federal statutory depletion			549			522			36
	Other			(52	)		34			(204	)
			$	(3,724	)	$	(12,154	)	$	(16,836	)
	Deferred income taxes reflect the net difference between the financial statement carrying amounts and the underlying income tax basis in such items.  The components of the federal deferred tax asset (liability) are as follows (in thousands):
			Years Ended December 31,
			2014			2013
	Current deferred tax asset (liability)
	Allowance for doubtful accounts		$	62		$	424
	Prepaid and other insurance			(719	)		(855	)
	Fair value contracts			(1	)		73
	Net current deferred liability			(658	)		(358	)
	Long-term deferred tax asset (liability)
	Property			(12,673	)		(18,964	)
	Uniform capitalization			661			613
	Other			(170	)		(283	)
	Net long-term deferred tax  liability			(12,182	)		(18,634	)
	Net deferred tax liability		$	(12,840	)	$	(18,992	)
	Financial statement recognition and measurement of positions taken, or expected to be taken, by an entity in its income tax returns must consider the uncertainty and judgment involved in the determination and filing of income taxes.  Tax positions taken in an income tax return that are recognized in the financial statements must satisfy a more-likely-than-not recognition threshold, assuming that the tax position will be examined by taxing authorities with full knowledge of all relevant information.  The Company has no significant unrecognized tax benefits.  Interest and penalties associated with income tax liabilities are classified as income tax expense.
	The earliest tax years remaining open for audit for federal and major states of operations are as follows:
		Earliest Open
		Tax Year
	Federal	2011
	Texas	2010
	Louisiana	2011
	Michigan	2011

Concentration_of_Credit_Risk

Concentration of Credit Risk	12 Months Ended
	Dec. 31, 2014
Concentration of Credit Risk [Abstract]
Concentration of Credit Risk	(3)  Concentration of Credit Risk
	Credit risk represents the amount of loss the Company would absorb if its customers fail to perform pursuant to contractual terms.  Management of credit risk involves a number of considerations, such as the financial profile of the customer, the value of collateral held, if any, specific terms and duration of the contractual agreement, and the customer’s sensitivity to economic developments.  The Company has established various procedures to manage credit exposure, including initial credit approval, credit limits, and rights of offset.  Letters of credit and guarantees are also utilized to limit credit risk. Accounts receivable associated with crude oil marketing activities comprise approximately 90 percent of the Company’s total receivables and industry practice requires payment for such sales to occur within 20 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.
	The Company’s largest customers consist of large multinational integrated oil companies and independent domestic refiners of crude oil.  In addition, the Company transacts business with independent oil producers, major chemical concerns, crude oil trading companies and a variety of commercial energy users.  Within this group of customers, the Company generally derives approximately 50 percent of its revenues from three to five 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.
	During 2014, the Company had revenues from two customers that comprised 20.3 percent and 14.0 percent, respectively, of total revenues.  The Company had revenues from four customers in 2013 that comprised 18.5 percent, 17.7 percent, 15.8 percent and 10.4 percent of total revenues, respectively.  During 2012, three customers comprised 20.2 percent, 17.9 percent and 16.8 percent of total revenues.
	As of December 31, 2014 the Company had accounts receivable from three customers that comprised 16.6 percent, 16.6 percent and 10.4 percent, respectively, of total accounts receivable.  As of December 31, 2013 the Company had accounts receivable from three customers that comprised 16.0 percent, 15.8 percent and 12.7 percent, respectively of total accounts receivables.  As of December 31, 2012 three customers comprised 22.1 percent, 21.4 percent and 11.4 percent, respectively, of total accounts receivable.
	An allowance for doubtful accounts is provided where appropriate and accounts receivable presented herein are net of allowances for doubtful accounts of $179,000 and $252,000 at December 31, 2014 and 2013, respectively.
	An analysis of the changes in the allowance for doubtful accounts is presented as follows (in thousands):
		2014			2013			2012
	Balance, beginning of year	$	252		$	206		$	357
	Provisions for bad debts		50			147			-
	Less:  Write-offs and recoveries		(123	)		(101	)		(151	)
	Balance, end of year	$	179		$	252		$	206

Employee_Benefits

Employee Benefits	12 Months Ended
	Dec. 31, 2014
Employee Benefits [Abstract]
Employee Benefits	(4)  Employee Benefits
	The Company maintains a 401(k) savings plan for the benefit of its employees.  The Company’s contributory expenses for the plan were $691,000, $674,000 and $645,000 in 2014, 2013 and 2012, respectively. No other pension or retirement plans are maintained by the Company.

Transactions_with_Affiliates

Transactions with Affiliates	12 Months Ended
	Dec. 31, 2014
Transactions with Affiliates [Abstract]
Transactions with Affiliates	(5)  Transactions with Affiliates
	The late Mr. K. S. Adams, Jr., former Chairman of the Board and certain of his family partnerships and affiliates have participated as working interest owners with the Company’s subsidiary, Adams Resources Exploration Corporation (‟AREC”).  Mr. Adams and the affiliates participated on terms similar to those afforded other non-affiliated working interest owners.  While the affiliates have generally maintained their existing property interest, they have not participated in any such transactions originating after the death of Mr. Adams in October 2013.  As of December 31, 2014 and 2013, the Company owed a combined net total of $51,000 and $38,000, 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 $151,000, $152,000 and $152,000 for the years ended December 31, 2014, 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 administrative services.  For the years ended December 31, 2014, 2013 and 2012, the affiliated entities charged the Company $65,000, $69,000 and $64,000, respectively, of expense reimbursement and the Company charged the affiliates $42,000, $99,000 and $98,000, respectively, for such expense reimbursements. The Company also leases its corporate office space in a building operated by an affiliated entity.  The lease rental rate was determined by an independent appraisal.  Rental expense paid to the related party for 2014 and 2013 totaled $607,000 and $481,000, respectively.  Additionally, in 2014, the Company engaged a professional services firm controlled by Townes Pressler, a member of the Company’s Board of Directors, to conduct a crude oil supply availability study.  Total study costs incurred were $70,420.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies [Abstract]
Commitments and Contingencies	(6)  Commitments and Contingencies
	The Company maintains certain operating lease arrangements with independent truck owner-operators for use of their equipment and driver services on a month-to-month basis. In addition, the Company has entered into certain lease and terminal access contracts in order to provide tank storage and dock access for its crude oil marketing business.  All operating lease commitments qualify for off-balance sheet treatment.  Such contracts require certain minimum monthly payments for the term of the contracts.  Rental expense for the years ended December 31, 2014, 2013, and 2012 was $9,755,000, $8,281,000 and $8,110,000, respectively.  At December 31, 2014, commitments under long-term non-cancelable operating leases and terminal arrangements for the next five years and thereafter are payable as follows:   2015 - $6,075,000; 2016 - $6,118,000; 2017 - $4,106,000; 2018 - $1,666,000; 2019 - $308,000 and none thereafter.
	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 liabilities related to these policies for losses incurred but not reported to the Company or its insurance carrier of $2,585,000 and $1,796,000 as of December 31, 2014 and 2013, respectively.
	The Company maintains a self-insurance program for managing employee medical claims.  A liability for expected claims incurred is established on a monthly basis and as claims are paid, the liability is relieved.  As of December 31, 2014 and 2013, accrued medical claims totaled $1,057,000 and $1,129,000, 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 years 2014 and 2015.
	AREC is named as a defendant in a number of Louisiana based suits involving alleged environmental contamination from prior drilling operations.  Such suits typically allege improper disposal of oilfield wastes in earthen pits with one suit alleging subsidence contributing of the formation of a sink hole.  AREC is currently involved in three such suits.  The suits are styled LePetit Chateau Deluxe v. Adams Resources Exploration Corporation dated March 2004, Gustave J. LaBarre, Jr., et. al. v. Adams Resources Exploration Corporation et al dated October 2012 and Henning Management, LLC v. Adams Resources Exploration Corporation dated November 2013.  Each suit involves multiple industry defendants with substantially larger proportional interest in the properties except all the larger defendants have settled their claims in the LePetit Chateau Deluxe matter.  The plaintiffs in each of these matters are seeking unspecified compensatory and punitive damages.    In August 2014, AREC was dismissed from a similar suit styled Edward Conner, et al v. Adams Resources Exploration Corporation dated October 2013.  While management does not believe that a material adverse effect will result from the claims, significant attorney fees will be incurred to defend these items.  As of December 31, 2014 and 2013, the Company has accrued $500,000 and $200,000, respectively, of future legal and/or settlement costs for these matters.
	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, therefore could potentially represent a material adverse effect on the Company’s financial position or results of operations.

Guarantees

Guarantees	12 Months Ended
	Dec. 31, 2014
Guarantees [Abstract]
Guarantees	(7)  Guarantees
	ARE issues parent guarantees of commitments associated with the activities of its subsidiary companies.  The guarantees generally result from subsidiary commodity purchase obligations, subsidiary operating lease commitments and subsidiary banking transactions.  The nature of such items is to guarantee the performance of the subsidiary companies in meeting their respective underlying obligations.  Except for operating lease commitments and letters of credit, all such underlying obligations are recorded on the books of the subsidiary companies and are included in the Consolidated Financial Statements included herein.  Therefore, no such obligation is recorded again on the books of the parent.  The parent would only be called upon to perform under the guarantee in the event of a payment default by the applicable subsidiary company.  In satisfying such obligations, the parent would first look to the assets of the defaulting subsidiary company.
	As of December 31, 2014, parental guaranteed obligations are approximately as follows (in thousands):
		2015		2016		2017		2018		Thereafter		Total
	Commodity purchases	$	41,110		-		-		-		-	$	41,110
	Letters of credit		15,300		-		-		-		-		15,300
		$	56,410	$	-	$	-	$	-	$	-	$	56,410
	Presently, neither ARE nor any of its subsidiaries has any other types of guarantees outstanding that require liability recognition.

Segment_Reporting

Segment Reporting	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Reporting	(8)  Segment Reporting
	The Company is engaged in the business of crude oil 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):
						Segment Operating			Depreciation Depletion and			Property and Equipment
			Revenues			Earnings (loss)			Amortization			Additions
	Year ended December 31, 2014-
	Marketing		$	4,050,497		$	20,854	-1	$	9,626		$	13,598
	Transportation			68,968			4,750			7,416			8,994
	Oil and gas			13,361			(7,510	)(2)		7,573			7,931
			$	4,132,826		$	18,094		$	24,615		$	30,523
	Year ended December 31, 2013-
	Marketing		$	3,863,057		$	40,369	-1	$	7,682		$	11,343
	Transportation			68,783			5,180			7,099			3,165
	Oil and gas			14,129			(2,113	)(2)		7,494			13,094
			$	3,945,969		$	43,436		$	22,275		$	27,602
	Year ended December 31, 2012-
	Marketing		$	3,292,948		$	46,145	-1	$	5,945		$	12,391
	Transportation			67,183			10,253			5,921			15,538
	Oil and gas			15,954			(3,632	)(2)		8,848			23,083
			$	3,376,085		$	52,766		$	20,714		$	51,012
		__________________________________
		(1) Marketing segment operating earnings included inventory liquidation and valuation losses totaling $14,247,000, $3,824,000 and $1,596,000 for 2014, 2013 and 2012, respectively.
		(2) Oil and gas segment operating earnings include gains on property sales totaling $2,528,000 and $2,203,000 during 2014 and 2012, respectively, and property impairments totaling $8,009,000, $2,630,000 and $5,555,000 for 2014, 2013 and 2012, respectively.
	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):
			Years Ended December 31,
			2014			2013			2012
	Segment operating earnings		$	18,094		$	43,436		$	52,766
	- General and administrative expenses			(8,613	)		(9,060	)		(8,810	)
	Operating earnings			9,481			34,376			43,956
	- Interest income			301			198			190
	- Interest expense			(2	)		(24	)		(10	)
	Earnings from continuing operations before
	income taxes and discontinued operations		$	9,780		$	34,550		$	44,136
	Identifiable assets by industry segment are as follows (in thousands):
			Years Ended December 31,
			2014			2013			2012
	Marketing		$	189,332		$	306,693		$	277,920
	Transportation			37,643			34,406			38,940
	Oil and gas			25,888			37,093			35,788
	Cash and other			87,951			69,890			66,853
			$	340,814		$	448,082		$	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.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2014
Discontinued Operations [Abstract]
Discontinued Operations	(9)  Discontinued Operations
	In February 2012, the Company completed the sale of contracts, inventory and certain equipment associated with the former refined products segment of its marketing business.  Revenues from this segment included in net earnings from discontinued operations totaled $25,717,000 for 2012.  The business had experienced marginal results including an operating loss during 2011.  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.  A pre-tax gain net of wind-down costs recognized from this transaction in 2012 totaled $808,000.  The Company’s fee interest in certain parcels of real estate were initially retained but were sold in 2014 for cash proceeds totaling $664,000 with a pre-tax gain of $553,000 included in 2014 results from discontinued operations.
	Due to inadequate earnings, the Company completed an orderly wind-down and closure of its natural gas marketing segment effective October 31, 2013.  Revenues from this segment included in net earnings from discontinued operations totaled $2,377,000 and $4,879,000 for the years ended December 31, 2013 and 2012, respectively.  All obligations were satisfied and no further events are anticipated.

Quarterly_Financial_Data_Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Data (Unaudited) [Abstract]
Quarterly Financial Data (Unaudited)	(10)  Quarterly Financial Data (Unaudited)
	Selected quarterly financial data and earnings per share of the Company are presented below for the years ended December 31, 2014 and 2013 (in thousands, except per share data):
					Earnings (Loss) from
					Continuing Operations						Net Earnings (Loss)						Dividends
			Revenues		Amount			Per Share			Amount			Per Share			Amount		Per Share
		2014 -
	31-Mar		$	949,189	$	5,363		$	1.27		$	5,363		$	1.27		$	928	$	0.22
	30-Jun			1,159,931		3,975			0.94			3,975			0.94			928		0.22
	30-Sep			1,173,970		3,855			0.92			3,855			0.92			928		0.22
	31-Dec			849,736		(6,974	)		(1.65	)		(6,670	)		(1.58	)		927		0.22
	Total		$	4,132,826	$	6,219		$	1.48		$	6,523		$	1.55		$	3,711	$	0.88
		2013 -
	31-Mar		$	952,435	$	8,073		$	1.91		$	8,015		$	1.9		$	-	$	-
	30-Jun			965,098		6,521			1.55			6,330			1.5			928		0.22
	30-Sep			1,060,340		7,238			1.72			7,156			1.7			927		0.22
	31-Dec			968,096		289			0.06			109			0.02			928		0.22
	Total		$	3,945,969	$	22,121		$	5.24		$	21,610		$	5.12		$	2,783	$	0.66
	The above unaudited interim financial data reflect all adjustments that are in the opinion of management necessary to a fair statement of the results for the period presented.  All such adjustments are of a normal recurring nature.

Oil_and_Gas_Producing_Activiti

Oil and Gas Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2014
Oil and Gas Producing Activities (Unaudited) [Abstract]
Oil and Gas Producing Activities (Unaudited)	(11) Oil and Gas Producing Activities (Unaudited)
	The Company’s oil and gas exploration and production activities are conducted in Texas and the south central region of the United States, primarily along the Gulf Coast of Texas and Louisiana.
	Oil and Gas Producing Activities -
	Total costs incurred in oil and gas exploration and development activities, all within the United States, were as follows (in thousands):
		For the year Ended December 31,
		2014			2013			2012
	Property acquisition costs
	Unproved	$	1,144		$	1,444		$	1,965
	Proved		-			-			-
	Exploration costs
	Expensed		5,054			1,619			1,151
	Capitalized		-			-			-
	Development costs		1,745			10,160			20,219
	Total costs incurred	$	7,943		$	13,223		$	23,335
	The aggregate capitalized costs relative to oil and gas producing activities are as follows (in thousands):
		As of December 31,
		2014			2013
	Unproved oil and gas properties	$	3,104		$	7,578
	Proved oil and gas properties		85,557			91,369
			88,661			98,947
	Accumulated depreciation, depletion
	and amortization		(64,682	)		(64,169	)
	Net capitalized cost	$	23,979		$	34,778
	Estimated Oil and Natural Gas Reserves  -
	The following information regarding estimates of the Company’s proved oil and gas reserves, all located in Texas and the south central region of the United States, is based on reports prepared on behalf of the Company by its independent petroleum engineers. Because oil and gas reserve estimates are inherently imprecise and require extensive judgments of reservoir engineering data, they are generally less precise than estimates made in conjunction with financial disclosures. The revisions of previous estimates as reflected in the table below result from changes in commodity pricing assumptions and from more precise engineering calculations based upon additional production histories and price changes.
	Proved developed and undeveloped reserves are presented as follows (in thousands):
		Years Ended December 31,
		2014						2013						2012
		Natural						Natural						Natural
		Gas			Oil			Gas			Oil			Gas			Oil
		(Mcf’s)			(Bbls.)			(Mcf’s)			(Bbls.)			(Mcf’s)			(Bbls.)
	Total proved reserves-
	Beginning of year		6,286			368			8,837			307			9,661			292
	Revisions of previous estimates		724			6			(1,438	)		(17	)		(507	)		29
	Oil and gas reserves sold		(558	)		(11	)		(28	)		-			(104	)		(54	)
	Extensions, discoveries and
	other reserve additions		292			82			523			180			2,395			138
	Production		(1,133	)		(127	)		(1,608	)		(102	)		(2,608	)		(98	)
	End of year		5,611			318			6,286			368			8,837			307
	The components of proved oil and gas reserves for the three years ended December 31, 2014 is presented below.  All reserves are in the United States (in thousands):
		Years Ended December 31,
		2014						2013						2012
		Natural						Natural						Natural
		Gas			Oil			Gas			Oil			Gas			Oil
		(Mcf’s)			(Bbls.)			(Mcf’s)			(Bbls.)			(Mcf’s)			(Bbls.)
	Proved developed reserves		5,482			299			6,157			367			8,708			306
	Proved undeveloped reserves		129			19			129			1			129			1
	Total proved reserves		5,611			318			6,286			368			8,837			307
	The Company has developed internal policies and controls for estimating and recording oil and gas reserve data.  The estimation and recording of proved reserves is required to be in compliance with SEC definitions and guidance.  The Company assigns responsibility for compliance in reserve bookings to the office of President of AREC.  No portion of this individual’s compensation is directly dependent on the quantity of reserves booked.  Reserve estimates are required to be made by qualified reserve estimators, as defined by Society of Petroleum Engineers’ Standards.
	The Company employed third party petroleum consultant, Ryder Scott Company, to prepare its oil and gas reserve data estimates as of December 31, 2014, 2013 and 2012.  The firm of Ryder Scott is well recognized within the industry for more than 50 years.  As prescribed by the SEC, such proved reserves were estimated using 12-month average oil and gas prices, based on the first-day-of-the-month price for each month in the period, and year-end production and development costs for each of the years presented, all without escalation.
	The process of estimating oil and gas reserves is complex and requires significant judgment.  Uncertainties are inherent in estimating quantities of proved reserves, including many factors beyond the estimator’s control.  Reserve engineering is a subjective process of estimating subsurface accumulations of oil and gas that cannot be measured in an exact manner, and the accuracy of any reserve estimate is a function of the quality of available data and the interpretation thereof.  As a result, assessments by different engineers often vary, sometimes significantly.  In addition, physical factors such as the results of drilling, testing and production subsequent to the date of an estimate, as well as economic factors such as changes in product prices, may justify revision of such estimates.  Accordingly, oil and gas quantities ultimately recovered will vary from reserve estimates.
	Standardized Measure of Discounted Future Net Cash Flows from Oil and Gas Operations and Changes Therein  -
	The standardized measure of discounted future net cash flows was determined based on the economic conditions in effect at the end of the years presented, except in those instances where fixed and determinable gas price escalations are included in contracts.  The disclosures below do not purport to present the fair market value of the Company’s oil and gas reserves.  An estimate of the fair market value would also take into account, among other things, the recovery of reserves in excess of proved reserves, anticipated future changes in prices and costs, a discount factor more representative of the time value of money and risks inherent in reserve estimates.  The standardized measure of discounted future net cash flows is presented as follows (in thousands):
		Years Ended December 31,
		2014			2013			2012
	Future gross revenues	$	58,885		$	64,495		$	59,793
	Future costs -
	Lease operating expenses		(16,421	)		(19,207	)		(16,357	)
	Development costs		(1,068	)		(119	)		(299	)
	Future net cash flows before income taxes		41,396			45,169			43,137
	Discount at 10% per annum		(17,175	)		(17,729	)		(17,976	)
	Discounted future net cash flows
	before income taxes		24,221			27,440			25,161
	Future income taxes, net of discount at
10% per annum		(8,477	)		(9,604	)		(8,806	)
Standardized measure of discounted
future net cash flows	$	15,744		$	17,836		$	16,355
The reserve estimates provided at December 31, 2014, 2013 and 2012 are based on aggregate prices of $89.60, $94.99 and $93.85 per barrel for crude oil and $5.42, $4.69 and $3.51 per mcf for natural gas, respectively.  Such prices were based on the unweighted arithmetic average of the prices in effect on the first day of the month for each month of the respective twelve month periods as required by SEC regulations.  The prices reported in the reserve disclosures for natural gas include the value of associated natural gas liquids.  Hydrocarbon prices declined significantly during the fourth quarter of 2014.  Realized domestic crude oil prices averaged in the $54 per barrel range during the month of December with additional price declines continuing into 2015.
The effect of income taxes and discounting on the standardized measure of discounted future net cash flows is presented as follows (in thousands):
	Years ended December 31,
	2014			2013			2012
Future net cash flows before income taxes	$	41,396		$	45,169		$	43,137
Future income taxes		(14,489	)		(15,809	)		(15,098	)
Future net cash flows		26,907			29,360			28,039
Discount at 10% per annum		(11,163	)		(11,524	)		(11,684	)
Standardized measure of discounted
future net cash flows	$	15,744		$	17,836		$	16,355
The principal sources of changes in the standardized measure of discounted future net flows are as follows (in thousands):
	Years Ended December 31,
	2014			2013			2012
Beginning of year	$	17,836		$	16,355		$	20,931
Sale of oil and gas reserves		(981	)		-			(3,802	)
Net change in prices and production costs		(72	)		9,341			(5,313	)
New field discoveries and extensions, net of future
production costs		4,456			9,767			9,513
Sales of oil and gas produced, net of production costs		(6,590	)		(8,373	)		(8,953	)
Net change due to revisions in quantity estimates		2,460			(3,624	)		(940	)
Accretion of discount		1,773			1,797			1,944
Production rate changes and other		(4,265	)		(6,629	)		511
Net change in income taxes		1,127			(798	)		2,464
End of year	$	15,744		$	17,836		$	16,355
Results of Operations for Oil and Gas Producing Activities -
The results of oil and gas producing activities, excluding corporate overhead and interest costs, are as follows (in thousands):
	Years Ended December 31,
	2014			2013			2012
Revenues	$	13,361		$	14,129		$	15,954
Costs and expenses -
Production		(6,771	)		(5,756	)		(7,091	)
Producing property impairment		(4,001	)		(1,373	)		(4,699	)
Exploration		(5,054	)		(1,619	)		(1,151	)
Oil and natural gas property sale gain		2,528			-			2,203
Depreciation, depletion and amortization		(7,573	)		(7,494	)		(8,848	)
Operating income (loss) before income taxes		(7,510	)		(2,113	)		(3,632	)
Income tax benefit		2,628			739			1,271
Operating income (loss)	$	(4,882	)	$	(1,374	)	$	(2,361	)

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Summary of Significant Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation
	The accompanying consolidated financial statements include the accounts of Adams Resources & Energy, Inc., a Delaware corporation (‟ARE”) together with its wholly owned subsidiaries (the ‟Company”) after elimination of all intercompany accounts and transactions.  The impact on the accompanying financial statements of events occurring after December 31, 2014 was evaluated through the date of issuance of these financial statements.
Nature of Operations	Nature of Operations
	The Company is engaged in the business of crude oil marketing, 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.
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.
Marketable Securities	Marketable Securities
	From time to time, the Company may invest in marketable securities consisting of investment grade corporate bonds traded in liquid markets.  Such bonds are held for the purpose of investing in liquid funds and are not generally intended to be retained on a long term basis.  Marketable securities are initially recognized at acquisition costs inclusive of transaction costs and are classified as trading securities.  In subsequent periods, marketable securities are valued at fair value.  Changes in these fair values are recognized as gains or losses in the accompanying statement of operations under the caption ‟Costs and Expenses – Marketing”.  Interest on marketable securities is recognized directly in the statement of operations during the period earned.
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts
	Accounts receivable are the product of sales of crude oil and natural gas and the sale of trucking services.  Marketing segment wholesale level sales of crude oil comprise in excess of 90 percent of total accounts receivable and under industry practices, such items are ‟settled” and paid in cash within 20 days of the month following the transaction date.  For such receivables, an allowance for doubtful accounts is determined based on specific account identification.  The balance of accounts receivable results primarily from the sale of trucking services.  For this component of receivables, the allowance for doubtful accounts is determined based on a review of specific accounts combined with a review of the general status of the aging of all accounts.
Inventories	Inventories
	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.  Due to declining crude oil prices, for the years ended December 31, 2014 and 2013 the Company recorded inventory liquidation and valuation losses totaling $14,247,000 and $3,824,000, respectively.
Prepayments	Prepayments
	The components of prepayments and other are as follows (in thousands):
			December 31,
			2014			2013
	Cash collateral deposits for commodity purchases		$	7,872		$	13,705
	Insurance premiums			2,316			2,490
	Rents, license and other			752			584
			$	10,940		$	16,779
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.
	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 December 31, 2014 and 2013, the Company had no unevaluated or suspended exploratory drilling costs.
	Depreciation, depletion and amortization of the cost of proved oil and gas properties is calculated using the unit-of-production method.  The reserve base used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves.  For lease and well equipment, development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves.  All other property and equipment is depreciated using the straight-line method over the estimated average useful lives of three to twenty years.
	The Company 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 and 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 years ended December 31, 2014, 2013 and 2012, there were $4,001,000, $1,373,000 and $4,699,000 respectively, of impairment provisions on producing oil and gas properties.
	Fair value measurements for producing oil and gas properties that were subject to fair value impairment for the years ended December 31, 2014 and 2013 summarized as follows (in thousands):
			Producing Properties
			Subject to Fair
			Value Impairment
			2014			2013
	Net book value at January 1		$	10,180		$	13,180
	Property additions			469			5,661
	Depletion taken			(1,792	)		(3,727	)
	Impairment valuation loss			(4,001	)		(1,373	)
	Net book value at December 31		$	4,856		$	13,741
	Fair value measurements for producing oil and gas properties are based on Level 3 – Significant Unobservable Inputs – (see “Fair Value Measurements” below).
	On a quarterly basis, management 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 $4,008,000, $1,257,000 and $856,000 were recorded for the years ending December 31, 2014, 2013 and 2012, respectively.  Capitalized costs for non-producing oil and gas leasehold interests currently represent approximately four percent of remaining unamoritized oil and gas property carrying costs and categorize as follows (in thousands):
			December 31,			December 31,
			2014			2013
	South Texas Project acreage		$	357		$	4,217
	West Texas Project			-			116
	Napoleonville Louisiana acreage			48			162
	Other acreage areas			554			411
	Total Non-producing Leasehold Costs		$	959		$	4,906
	The South 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 interests, it does not maintain underlying detail acreage data and 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
			2014			2013
	Net book value January 1		$	411		$	329
	Property additions			580			304
	Property sale			-			-
	Impairments			(437	)		(222	)
	Net book value December 31		$	554		$	411
	During 2014, the Company sold substantially all of its producing property interests in Oklahoma.  Proceeds totaled $1,731,000 and the Company recorded a $1,149,000 pre-tax gain from this sale.  Also during 2014 the Company sold one-half of its interest in sections of its South Texas project interest.  Proceeds totaled $1,509,000 and the Company recorded a $632,000 pre-tax gain from this sale.  Certain other oil and gas property interests were also sold in 2014 for proceeds totaling $822,000 and gains totaling $747,000.  During 2012, the Company sold half of its interest in certain non-producing Kansas oil and gas properties.  Proceeds from the sale totaled $578,000 and the Company recorded a $475,000 pre-tax gain from this sale.  Also during 2012, the Company sold its interest in two oil and gas producing property units for total proceeds of $3,049,000.  The Company realized a $1,728,000 pre-tax gain from these two sales.
	During 2014, 2013 and 2012, the Company sold certain used trucks and equipment from its marketing and transportation segments and recorded net pre-tax gains totaling $1,028,000, $683,000 and $2,482,000, respectively.
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):
			December 31,
			2014			2013
	Insurance collateral deposits		$	4,536		$	3,718
	State collateral deposits			155			160
	Materials and supplies			307			609
			$	4,998		$	4,487
Revenue Recognition	Revenue Recognition
	Commodity purchase and sale contracts utilized by the Company’s marketing business generally qualify as derivative instruments with certain specifically identified crude oil contracts 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 consolidated financial statements.
	Most all crude oil purchase 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 consolidated financial statements.  Reporting such crude oil contracts on a gross revenue basis would increase the Company’s reported revenues by $1,272,034,000, $1,602,626,000 and $1,381,352,000 for the years ended December 31, 2014, 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.
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 purchases within the marketing segment.  This facility is collateralized by the eligible accounts receivable within the segment and certain marketing and transportation equipment.  Stand-by letters of credit issued totaled $15.3 million and $14.6 million as of December 31, 2014 and 2013, 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. subsidiary.  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 $2,000, $24,000 and $10,000 during the years ended December 31, 2014, 2013 and 2012, respectively.  Federal and state income taxes paid during these same periods totaled $8,169,000, $9,949,000, and $12,650,000, respectively.  In addition, State income tax refunds totaled $18,615, $4,000 and $10,000 in 2014, 2013 and 2012, respectively.  Non-cash investing activities for property and equipment items included in accounts payable as of period end were $1,137,000, $1,507,000 and $2,419,000 as of December 31, 2014, 2013 and 2012, 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. The weighted average number of shares outstanding was 4,217,596 for 2014, 2013 and 2012.  There were no potentially dilutive securities outstanding 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 the oil and gas reserve volumes that form the foundation for calculating depreciation, depletion and amortization and estimating cash flows to assess impairment triggers and estimated 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 (See also Note (2).
Use of Derivative Instruments	Use of Derivative Instruments
	The Company’s marketing segment is involved in the purchase and sale of crude oil.  The Company seeks to make a profit by procuring this commodity as it is produced and then delivering the material to end users or the 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.  Some 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 wholesale distribution businesses. None of the Company’s derivative instruments have been designated as hedging instruments.  The accounting methodology utilized by the Company for its commodity contracts is further discussed below under the caption ‟Fair Value Measurements”.
	The estimated fair value of forward month commodity contracts (derivatives) is reflected in the accompanying Consolidated Balance Sheet as of December 31, 2014 as follows (in thousands):
			Balance Sheet Location and Amount
			Current			Other			Current			Other
			Assets			Assets			Liabilities			Liabilities
	Asset Derivatives
	- Fair Value Commodity
	Contracts at Gross Valuation		$	1,332		$	-		$	-		$	-
	Liability Derivatives
	- Fair Value Commodity
	Contracts at Gross Valuation			-			-			1,339			-
	Less Counterparty Offsets			(396	)		-			(396	)		-
	As Reported Fair Value Contracts		$	936		$	-		$	943		$	-
	As of December 31, 2014, three purchase and sale contracts comprised the Company’s derivative valuations.  The purchase and sale contracts encompass approximately 294 barrels of crude oil per day in each of January and February 2015 and 129 barrels of crude oil per day in March through December 2015.
	The estimated fair value of forward month commodity contracts (derivatives) is reflected in the accompanying Consolidated Balance Sheet as of December 31, 2013 as follows (in thousands):
			Balance Sheet Location and Amount
			Current			Other			Current			Other
			Assets			Assets			Liabilities			Liabilities
	Asset Derivatives
	- Fair Value Commodity
	Contracts at Gross Valuation		$	449		$	-		$	-		$	-
	Liability Derivatives
	- Fair Value Commodity
	Contracts at Gross Valuation			-			-			54			-
	Less Counterparty Offsets			(54	)		-			(54	)		-
	As Reported Fair Value Contracts		$	395		$	-		$	-		$	-
	As of December 31, 2013, one 100,000 barrel crude oil commodity put option and one commodity purchase and sales contract comprised the Company’s derivative valuations.  The purchase and sale contract encompassed 175 barrels of crude oil per day in each of January and February 2014.
	The Company only enters into commodity contracts with creditworthy counterparties or obtains collateral support for such activities.  As of December 31, 2014 and 2013, the Company was not holding nor had it posted any collateral to support its forward month fair value derivative activity. The Company is not subject to any credit-risk related trigger events.  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 Consolidated Statement of Operations for the years ended December 31, 2014, 2013 and 2012 as follows (in thousands):
			Gain (Loss)
	Location		2014			2013			2012
	Revenues – marketing		$	312		$	(193	)	$	(1,365	)
Fair Value Measurements	Fair Value Measurements
	The carrying amount reported in the Consolidated Balance Sheet for cash and cash equivalents, accounts receivable and accounts payable approximates fair value because of the immediate or short-term maturity of these financial instruments.  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 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 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 valuations 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, 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 December 31, 2014, 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		$	-		$	1,332		$	-		$	(396	)	$	936
	- Current liabilities			-			(1,339	)		-			396			(943	)
	Net Value		$	-		$	(7	)	$	-		$	-		$	(7	)
	As of December 31, 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		$	-		$	449		$	-		$	(54	)	$	395
	- Current liabilities			-			(54	)		-			54			-
	Net Value		$	-		$	395		$	-		$	-		$	395
	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 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 December 31, 2014 and 2013, credit valuation adjustments were not significant to the overall valuation of the Company’s fair value contracts.  As a result, fair value assets and liabilities are included in their entirety in the fair value hierarchy.
	The following table illustrates the factors impacting the change in the net value of the Company’s fair value contracts for the year ended December 31, 2014 (in thousands):
			Level 1			Level 2
			Quoted Prices			Observable			Total
	Net Fair Value January 1,		$	-		$	395		$	395
	- Net realized (gains) losses			-			220			220
	- Option gain			-			99			99
	- Option collateral			-			(714	)		(714	)
	- Net unrealized gains (losses)			-			(7	)		(7	)
	Net Fair Value December 31,		$	-		$	(7	)	$	(7	)
	The following table illustrates the factors impacting the change in the net value of the Company’s fair value contracts for the year ended December 31, 2013 (in thousands):
			Level 1			Level 2
			Quoted Prices			Observable			Total
	Net Fair Value January 1,		$	-		$	(27	)	$	(27	)
	- Net realized (gains) losses			-			27			27
	- Option deposit			-			615			615
	- Net unrealized gains (losses)			-			(220	)		(220	)
	Net Fair Value December 31,		$	-		$	395		$	395
Asset Retirement Obligations	Asset Retirement Obligations
	The Company records a liability for the estimated retirement costs associated with certain tangible long-lived assets.  The estimated fair value of asset retirement obligations are recorded in the period in which they are incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the asset or the units of production associated with the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.  A summary of the Company’s asset retirement obligations is presented as follows (in thousands):
			2014			2013
	Balance on January 1		$	2,564		$	1,886
	-Liabilities incurred			111			431
	-Accretion of discount			94			85
	-Liabilities settled			(305	)		(138	)
	-Revisions to estimates			-			300
	Balance on December 31		$	2,464		$	2,564
	In addition to an accrual for asset retirement obligations, the Company maintains $75,000 in escrow cash, which is legally restricted for the potential purpose of settling asset retirement costs in accordance with certain state regulations.  Such cash deposits are included in other assets in the accompanying consolidated balance sheet.
Recent Accounts Pronouncement	Recent Accounts Pronouncement
	In April 2014, the Financial Accounting Standards Board (‟FASB”) issued updated guidance changing the criteria for reporting discontinued operations including enhanced disclosure requirements.  Under the new guidance, only activities representing a strategic shift in operations are presented as discontinued operations.  Such strategic shifts are those having a major effect on the organization’s operations and financial results.  The Company adopted the new guidance effective July 1, 2014 and the adoption did not have a material effect on the Consolidated Financial Statements.
	In May 2014, the FASB amended the existing accounting standards for revenue recognition.  The amendments are based on the principle that revenue should be recognized to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.  The new guidance is effective for the annual period ending after December 15, 2016.  Early adoption is not permitted.  The amendments may be applied retrospectively to each prior period presented or retrospectively with the cumulative effect recognized as of the date of initial application.  Management is currently evaluating the impact of these amendments on the Company’s consolidated financial statements and the transition alternatives.
	In August 2014, the FASB issued guidance requiring management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued.  The standard also provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements.  The new guidance is effective for the annual period ending after December 15, 2016, and interim periods thereafter, with early adoption permitted.  Management does not expect the adoption of this guidance to have an impact on the Consolidated Financial Statements.
	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.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Summary of Significant Accounting Policies [Abstract]
Components of prepayments and other	The components of prepayments and other are as follows (in thousands):
		December 31,
		2014			2013
	Cash collateral deposits for commodity purchases	$	7,872		$	13,705
	Insurance premiums		2,316			2,490
	Rents, license and other		752			584
		$	10,940		$	16,779
Fair value measurements for producing oil and gas properties that were subject to fair value impairment	Fair value measurements for producing oil and gas properties that were subject to fair value impairment for the years ended December 31, 2014 and 2013 summarized as follows (in thousands):
		Producing Properties
		Subject to Fair
		Value Impairment
		2014			2013
	Net book value at January 1	$	10,180		$	13,180
	Property additions		469			5,661
	Depletion taken		(1,792	)		(3,727	)
	Impairment valuation loss		(4,001	)		(1,373	)
	Net book value at December 31	$	4,856		$	13,741
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 remaining unamoritized oil and gas property carrying costs and categorize as follows (in thousands):
		December 31,			December 31,
		2014			2013
	South Texas Project acreage	$	357		$	4,217
	West Texas Project		-			116
	Napoleonville Louisiana acreage		48			162
	Other acreage areas		554			411
	Total Non-producing Leasehold Costs	$	959		$	4,906
Capitalized cost activity on the other acreage areas	Capitalized cost activity on the ‟Other Acreage Areas” was as follows (in thousands):
		Leasehold Costs
		2014			2013
	Net book value January 1	$	411		$	329
	Property additions		580			304
	Property sale		-			-
	Impairments		(437	)		(222	)
	Net book value December 31	$	554		$	411
Components of cash deposits and other assets	Components of cash deposits and other assets are as follows (in thousands):
		December 31,
		2014			2013
	Insurance collateral deposits	$	4,536		$	3,718
	State collateral deposits		155			160
	Materials and supplies		307			609
		$	4,998		$	4,487
Derivatives reflected in the Consolidated Balance Sheet	The estimated fair value of forward month commodity contracts (derivatives) is reflected in the accompanying Consolidated Balance Sheet as of December 31, 2014 as follows (in thousands):
		Balance Sheet Location and Amount
		Current			Other			Current			Other
		Assets			Assets			Liabilities			Liabilities
	Asset Derivatives
	- Fair Value Commodity
	Contracts at Gross Valuation	$	1,332		$	-		$	-		$	-
	Liability Derivatives
	- Fair Value Commodity
	Contracts at Gross Valuation		-			-			1,339			-
	Less Counterparty Offsets		(396	)		-			(396	)		-
	As Reported Fair Value Contracts	$	936		$	-		$	943		$	-
	The estimated fair value of forward month commodity contracts (derivatives) is reflected in the accompanying Consolidated Balance Sheet as of December 31, 2013 as follows (in thousands):
		Balance Sheet Location and Amount
		Current			Other			Current			Other
		Assets			Assets			Liabilities			Liabilities
	Asset Derivatives
	- Fair Value Commodity
	Contracts at Gross Valuation	$	449		$	-		$	-		$	-
	Liability Derivatives
	- Fair Value Commodity
	Contracts at Gross Valuation		-			-			54			-
	Less Counterparty Offsets		(54	)		-			(54	)		-
	As Reported Fair Value Contracts	$	395		$	-		$	-		$	-
Derivatives reflected in the Consolidated Statement of Operations	Forward month commodity contracts (derivatives) are reflected in the accompanying Consolidated Statement of Operations for the years ended December 31, 2014, 2013 and 2012 as follows (in thousands):
		Gain (Loss)
	Location	2014			2013			2012
	Revenues – marketing	$	312		$	(193	)	$	(1,365	)
Fair value assets and liabilities	As of December 31, 2014, 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	$	-		$	1,332		$	-		$	(396	)	$	936
	- Current liabilities		-			(1,339	)		-			396			(943	)
	Net Value	$	-		$	(7	)	$	-		$	-		$	(7	)
	As of December 31, 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	$	-		$	449		$	-		$	(54	)	$	395
	- Current liabilities		-			(54	)		-			54			-
	Net Value	$	-		$	395		$	-		$	-		$	395
Factors impacting the change in the net value of the Company's fair value contracts	The following table illustrates the factors impacting the change in the net value of the Company’s fair value contracts for the year ended December 31, 2014 (in thousands):
		Level 1			Level 2
		Quoted Prices			Observable			Total
	Net Fair Value January 1,	$	-		$	395		$	395
	- Net realized (gains) losses		-			220			220
	- Option gain		-			99			99
	- Option collateral		-			(714	)		(714	)
	- Net unrealized gains (losses)		-			(7	)		(7	)
	Net Fair Value December 31,	$	-		$	(7	)	$	(7	)
	The following table illustrates the factors impacting the change in the net value of the Company’s fair value contracts for the year ended December 31, 2013 (in thousands):
		Level 1			Level 2
		Quoted Prices			Observable			Total
	Net Fair Value January 1,	$	-		$	(27	)	$	(27	)
	- Net realized (gains) losses		-			27			27
	- Option deposit		-			615			615
	- Net unrealized gains (losses)		-			(220	)		(220	)
	Net Fair Value December 31,	$	-		$	395		$	395
Company's asset retirement obligations	A summary of the Company’s asset retirement obligations is presented as follows (in thousands):
		2014			2013
	Balance on January 1	$	2,564		$	1,886
	-Liabilities incurred		111			431
	-Accretion of discount		94			85
	-Liabilities settled		(305	)		(138	)
	-Revisions to estimates		-			300
	Balance on December 31	$	2,464		$	2,564

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Taxes [Abstract]
Components of the Company's income tax (provision) benefit	The following table shows the components of the Company’s income tax (provision) benefit (in thousands):
			Years ended December 31,
			2014			2013			2012
	Current:
	Federal		$	(8,626	)	$	(8,102	)	$	(10,282	)
	State			(1,249	)		(892	)		(1,176	)
				(9,875	)		(8,994	)		(11,458	)
	Deferred:
	Federal			5,878			(2,682	)		(4,940	)
	State			273			(478	)		(438	)
				6,151			(3,160	)		(5,378	)
			$	(3,724	)	$	(12,154	)	$	(16,836	)
Income tax (provision) benefit allocable to continuing and discontinued operations	The following table summarizes the components of the income tax (provision) benefit (in thousands):
			Years ended December 31,
			2014			2013			2012
	From continuing operations		$	(3,561	)	$	(12,429	)	$	(16,664	)
	From discontinued operations			(163	)		275			(172	)
			$	(3,724	)	$	(12,154	)	$	(16,836	)
Reconciliation of taxes computed at the corporate federal income tax rate to the reported income tax (provision)	Taxes computed at the corporate federal income tax rate reconcile to the reported income tax (provision) as follows (in thousands):
			Years ended December 31,
			2014			2013			2012
	Statutory federal income tax (provision) benefit		$	(3,587	)	$	(11,819	)	$	(15,619	)
	State income tax (provision) benefit			(634	)		(891	)		(1,049	)
	Federal statutory depletion			549			522			36
	Other			(52	)		34			(204	)
			$	(3,724	)	$	(12,154	)	$	(16,836	)
Components of the federal deferred tax asset (liability)	Deferred income taxes reflect the net difference between the financial statement carrying amounts and the underlying income tax basis in such items.  The components of the federal deferred tax asset (liability) are as follows (in thousands):
			Years Ended December 31,
			2014			2013
	Current deferred tax asset (liability)
	Allowance for doubtful accounts		$	62		$	424
	Prepaid and other insurance			(719	)		(855	)
	Fair value contracts			(1	)		73
	Net current deferred liability			(658	)		(358	)
	Long-term deferred tax asset (liability)
	Property			(12,673	)		(18,964	)
	Uniform capitalization			661			613
	Other			(170	)		(283	)
	Net long-term deferred tax  liability			(12,182	)		(18,634	)
	Net deferred tax liability		$	(12,840	)	$	(18,992	)
Earliest tax years remaining for Federal and major states of operations	The earliest tax years remaining open for audit for federal and major states of operations are as follows:
		Earliest Open
		Tax Year
	Federal	2011
	Texas	2010
	Louisiana	2011
	Michigan	2011

Concentration_of_Credit_Risk_T

Concentration of Credit Risk (Tables)	12 Months Ended
	Dec. 31, 2014
Concentration of Credit Risk [Abstract]
Changes in the allowance for doubtful accounts	An analysis of the changes in the allowance for doubtful accounts is presented as follows (in thousands):
		2014			2013			2012
	Balance, beginning of year	$	252		$	206		$	357
	Provisions for bad debts		50			147			-
	Less:  Write-offs and recoveries		(123	)		(101	)		(151	)
	Balance, end of year	$	179		$	252		$	206

Guarantees_Tables

Guarantees (Tables)	12 Months Ended
	Dec. 31, 2014
Guarantees [Abstract]
Parental guaranteed obligations	As of December 31, 2014, parental guaranteed obligations are approximately as follows (in thousands):
		2015		2016		2017		2018		Thereafter		Total
	Commodity purchases	$	41,110		-		-		-		-	$	41,110
	Letters of credit		15,300		-		-		-		-		15,300
		$	56,410	$	-	$	-	$	-	$	-	$	56,410

Segment_Reporting_Tables

Segment Reporting (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Information concerning business activities and assets by segment	The Company is engaged in the business of crude oil 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):
						Segment Operating			Depreciation Depletion and			Property and Equipment
			Revenues			Earnings (loss)			Amortization			Additions
	Year ended December 31, 2014-
	Marketing		$	4,050,497		$	20,854	-1	$	9,626		$	13,598
	Transportation			68,968			4,750			7,416			8,994
	Oil and gas			13,361			(7,510	)(2)		7,573			7,931
			$	4,132,826		$	18,094		$	24,615		$	30,523
	Year ended December 31, 2013-
	Marketing		$	3,863,057		$	40,369	-1	$	7,682		$	11,343
	Transportation			68,783			5,180			7,099			3,165
	Oil and gas			14,129			(2,113	)(2)		7,494			13,094
			$	3,945,969		$	43,436		$	22,275		$	27,602
	Year ended December 31, 2012-
	Marketing		$	3,292,948		$	46,145	-1	$	5,945		$	12,391
	Transportation			67,183			10,253			5,921			15,538
	Oil and gas			15,954			(3,632	)(2)		8,848			23,083
			$	3,376,085		$	52,766		$	20,714		$	51,012
		__________________________________
		(1) Marketing segment operating earnings included inventory liquidation and valuation losses totaling $14,247,000, $3,824,000 and $1,596,000 for 2014, 2013 and 2012, respectively.
		(2) Oil and gas segment operating earnings include gains on property sales totaling $2,528,000 and $2,203,000 during 2014 and 2012, respectively, and property impairments totaling $8,009,000, $2,630,000 and $5,555,000 for 2014, 2013 and 2012, respectively.
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):
			Years Ended December 31,
			2014			2013			2012
	Segment operating earnings		$	18,094		$	43,436		$	52,766
	- General and administrative expenses			(8,613	)		(9,060	)		(8,810	)
	Operating earnings			9,481			34,376			43,956
	- Interest income			301			198			190
	- Interest expense			(2	)		(24	)		(10	)
	Earnings from continuing operations before
	income taxes and discontinued operations		$	9,780		$	34,550		$	44,136
Identifiable assets by industry segment	Identifiable assets by industry segment are as follows (in thousands):
			Years Ended December 31,
			2014			2013			2012
	Marketing		$	189,332		$	306,693		$	277,920
	Transportation			37,643			34,406			38,940
	Oil and gas			25,888			37,093			35,788
	Cash and other			87,951			69,890			66,853
			$	340,814		$	448,082		$	419,501

Quarterly_Financial_Data_Unaud1

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Data (Unaudited) [Abstract]
Selected quarterly financial data and earnings per share	Selected quarterly financial data and earnings per share of the Company are presented below for the years ended December 31, 2014 and 2013 (in thousands, except per share data):
					Earnings (Loss) from
					Continuing Operations						Net Earnings (Loss)						Dividends
			Revenues		Amount			Per Share			Amount			Per Share			Amount		Per Share
		2014 -
	31-Mar		$	949,189	$	5,363		$	1.27		$	5,363		$	1.27		$	928	$	0.22
	30-Jun			1,159,931		3,975			0.94			3,975			0.94			928		0.22
	30-Sep			1,173,970		3,855			0.92			3,855			0.92			928		0.22
	31-Dec			849,736		(6,974	)		(1.65	)		(6,670	)		(1.58	)		927		0.22
	Total		$	4,132,826	$	6,219		$	1.48		$	6,523		$	1.55		$	3,711	$	0.88
		2013 -
	31-Mar		$	952,435	$	8,073		$	1.91		$	8,015		$	1.9		$	-	$	-
	30-Jun			965,098		6,521			1.55			6,330			1.5			928		0.22
	30-Sep			1,060,340		7,238			1.72			7,156			1.7			927		0.22
	31-Dec			968,096		289			0.06			109			0.02			928		0.22
	Total		$	3,945,969	$	22,121		$	5.24		$	21,610		$	5.12		$	2,783	$	0.66

Oil_and_Gas_Producing_Activiti1

Oil and Gas Producing Activities (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Oil and Gas Producing Activities (Unaudited) [Abstract]
Cost incurred in oil and gas exploration and development activities	Total costs incurred in oil and gas exploration and development activities, all within the United States, were as follows (in thousands):
		For the year Ended December 31,
		2014			2013			2012
	Property acquisition costs
	Unproved	$	1,144		$	1,444		$	1,965
	Proved		-			-			-
	Exploration costs
	Expensed		5,054			1,619			1,151
	Capitalized		-			-			-
	Development costs		1,745			10,160			20,219
	Total costs incurred	$	7,943		$	13,223		$	23,335
Capitalized costs relating to oil and gas producing activities	The aggregate capitalized costs relative to oil and gas producing activities are as follows (in thousands):
		As of December 31,
		2014			2013
	Unproved oil and gas properties	$	3,104		$	7,578
	Proved oil and gas properties		85,557			91,369
			88,661			98,947
	Accumulated depreciation, depletion
	and amortization		(64,682	)		(64,169	)
	Net capitalized cost	$	23,979		$	34,778
Proved developed and undeveloped oil and gas reserves	Proved developed and undeveloped reserves are presented as follows (in thousands):
		Years Ended December 31,
		2014						2013						2012
		Natural						Natural						Natural
		Gas			Oil			Gas			Oil			Gas			Oil
		(Mcf’s)			(Bbls.)			(Mcf’s)			(Bbls.)			(Mcf’s)			(Bbls.)
	Total proved reserves-
	Beginning of year		6,286			368			8,837			307			9,661			292
	Revisions of previous estimates		724			6			(1,438	)		(17	)		(507	)		29
	Oil and gas reserves sold		(558	)		(11	)		(28	)		-			(104	)		(54	)
	Extensions, discoveries and
	other reserve additions		292			82			523			180			2,395			138
	Production		(1,133	)		(127	)		(1,608	)		(102	)		(2,608	)		(98	)
	End of year		5,611			318			6,286			368			8,837			307
Components of proved oil and gas reserves	The components of proved oil and gas reserves for the three years ended December 31, 2014 is presented below.  All reserves are in the United States (in thousands):
		Years Ended December 31,
		2014						2013						2012
		Natural						Natural						Natural
		Gas			Oil			Gas			Oil			Gas			Oil
		(Mcf’s)			(Bbls.)			(Mcf’s)			(Bbls.)			(Mcf’s)			(Bbls.)
	Proved developed reserves		5,482			299			6,157			367			8,708			306
	Proved undeveloped reserves		129			19			129			1			129			1
	Total proved reserves		5,611			318			6,286			368			8,837			307
Standardized measure of discounted future net cash flows	The standardized measure of discounted future net cash flows is presented as follows (in thousands):
		Years Ended December 31,
		2014			2013			2012
	Future gross revenues	$	58,885		$	64,495		$	59,793
	Future costs -
	Lease operating expenses		(16,421	)		(19,207	)		(16,357	)
	Development costs		(1,068	)		(119	)		(299	)
	Future net cash flows before income taxes		41,396			45,169			43,137
	Discount at 10% per annum		(17,175	)		(17,729	)		(17,976	)
	Discounted future net cash flows
	before income taxes		24,221			27,440			25,161
	Future income taxes, net of discount at
	10% per annum		(8,477	)		(9,604	)		(8,806	)
	Standardized measure of discounted
	future net cash flows	$	15,744		$	17,836		$	16,355
Effect of income taxes and discounting on the standardized measure of discounted future net cash flows	The effect of income taxes and discounting on the standardized measure of discounted future net cash flows is presented as follows (in thousands):
		Years ended December 31,
		2014			2013			2012
	Future net cash flows before income taxes	$	41,396		$	45,169		$	43,137
	Future income taxes		(14,489	)		(15,809	)		(15,098	)
	Future net cash flows		26,907			29,360			28,039
	Discount at 10% per annum		(11,163	)		(11,524	)		(11,684	)
	Standardized measure of discounted
	future net cash flows	$	15,744		$	17,836		$	16,355
Principal sources of changes in the standardized measure of discounted future net flows	The principal sources of changes in the standardized measure of discounted future net flows are as follows (in thousands):
		Years Ended December 31,
		2014			2013			2012
	Beginning of year	$	17,836		$	16,355		$	20,931
	Sale of oil and gas reserves		(981	)		-			(3,802	)
	Net change in prices and production costs		(72	)		9,341			(5,313	)
	New field discoveries and extensions, net of future
	production costs		4,456			9,767			9,513
	Sales of oil and gas produced, net of production costs		(6,590	)		(8,373	)		(8,953	)
	Net change due to revisions in quantity estimates		2,460			(3,624	)		(940	)
	Accretion of discount		1,773			1,797			1,944
	Production rate changes and other		(4,265	)		(6,629	)		511
	Net change in income taxes		1,127			(798	)		2,464
	End of year	$	15,744		$	17,836		$	16,355
Results of operations for oil and gas producing activities	The results of oil and gas producing activities, excluding corporate overhead and interest costs, are as follows (in thousands):
		Years Ended December 31,
		2014			2013			2012
	Revenues	$	13,361		$	14,129		$	15,954
	Costs and expenses -
	Production		(6,771	)		(5,756	)		(7,091	)
	Producing property impairment		(4,001	)		(1,373	)		(4,699	)
	Exploration		(5,054	)		(1,619	)		(1,151	)
	Oil and natural gas property sale gain		2,528			-			2,203
	Depreciation, depletion and amortization		(7,573	)		(7,494	)		(8,848	)
	Operating income (loss) before income taxes		(7,510	)		(2,113	)		(3,632	)
	Income tax benefit		2,628			739			1,271
	Operating income (loss)	$	(4,882	)	$	(1,374	)	$	(2,361	)

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	Contract	Contract
	mi
Nature of Operations [Abstract]
Primary area of operation (in miles)	1,000
Allowance for Doubtful Accounts [Abstract]
Percentage of crude oil and natural gas sales in accounts receivable (in hundredths)	90.00%
Number of days, cash is received from transaction date	20 days
Inventory [Abstract]
Inventory liquidation and valuation losses	$14,247,000	$3,824,000
Components of prepayments and other [Abstract]
Cash collateral deposits for commodity purchases	7,872,000	13,705,000
Insurance premiums	2,316,000	2,490,000
Rents, license and other	752,000	584,000
Prepayments, total	10,940,000	16,779,000
Property, Plant and Equipment [Line Items]
Exploratory drilling costs	0	0
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Property additions	7,943,000	13,223,000	23,335,000
Impairment valuation loss	-8,009,000	-2,630,000	-5,555,000
Total Non-producing Leasehold Costs	959,000	4,906,000
Pre-tax gain on sale of oil and gas properties	2,528,000	0	2,203,000
Pre-tax gain on sale of equipment	1,028,000	683,000	2,482,000
Cash Deposits and Other Assets [Abstract]
Insurance collateral deposits	4,536,000	3,718,000
State collateral deposits	155,000	160,000
Materials and supplies	307,000	609,000
Cash deposits and other	4,998,000	4,487,000
Revenue Recognition [Abstract]
Increase in the entity's reported revenue	1,272,034,000	1,602,626,000	1,381,352,000
Statement of Cash Flows [Abstract]
Interest paid	2,000	24,000	10,000
Income taxes paid	8,169,000	9,949,000	12,650,000
Proceeds from income tax refunds	18,615	4,000	10,000
Non-cash investing activities for property and equipment	1,137,000	1,507,000	2,419,000
Earnings Per Share [Abstract]
Weighted average number of shares outstanding (in shares)	4,217,596	4,217,596	4,217,596
Fair Value Forward Hydrocarbon Commodity Contracts at gross valuation [Abstract]
Number of contracts held	3	1
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Assets [Member]
Fair Value Forward Hydrocarbon Commodity Contracts at gross valuation [Abstract]
Asset Derivatives	1,332,000	449,000
Liability Derivatives	0	0
Less Counterparty Offsets	-396,000	-54,000
As Reported Fair Value Contracts	936,000	395,000
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Assets [Member]
Fair Value Forward Hydrocarbon Commodity Contracts at gross valuation [Abstract]
Asset Derivatives	0	0
Liability Derivatives	0	0
Less Counterparty Offsets	0	0
As Reported Fair Value Contracts	0	0
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Liabilities [Member]
Fair Value Forward Hydrocarbon Commodity Contracts at gross valuation [Abstract]
Asset Derivatives	0	0
Liability Derivatives	1,339,000	54,000
Less Counterparty Offsets	-396,000	-54,000
As Reported Fair Value Contracts	943,000	0
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Liabilities [Member]
Fair Value Forward Hydrocarbon Commodity Contracts at gross valuation [Abstract]
Asset Derivatives	0	0
Liability Derivatives	0	0
Less Counterparty Offsets	0	0
As Reported Fair Value Contracts	0	0
Commodity Contract [Member] | Jan 2014 to Feb 2014 [Member]
Fair Value Forward Hydrocarbon Commodity Contracts at gross valuation [Abstract]
Volume committed per day under commodity purchase and sale contract (in barrels)		175
Commodity Contract [Member] | Jan 2015 to Feb 2015 [Member]
Fair Value Forward Hydrocarbon Commodity Contracts at gross valuation [Abstract]
Volume committed per day under commodity purchase and sale contract (in barrels)	294
Commodity Contract [Member] | Mar 2015 to Dec 2015 [Member]
Fair Value Forward Hydrocarbon Commodity Contracts at gross valuation [Abstract]
Volume committed per day under commodity purchase and sale contract (in barrels)	129
Commodity Put Option [Member]
Fair Value Forward Hydrocarbon Commodity Contracts at gross valuation [Abstract]
Number of contracts held		1
Volume of crude oil committed under commodity put option (in barrels)		100,000
Wells Fargo Bank [Member]
Letter of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity	60,000,000
Standby letters of credit issued	15,300,000	14,600,000
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
Minimum [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	3 years
Maximum [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	20 years
Producing Oil and Gas Properties [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Impairment valuation loss	4,001,000	1,373,000	4,699,000
Proceeds from sale of oil and gas properties	1,731,000		3,049,000
Pre-tax gain on sale of oil and gas properties	1,149,000		1,728,000
Number of oil and gas producing properties sold			2
Producing Oil and Gas Properties Impaired in 2014 [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Net book value at January 1	10,180,000
Property additions	469,000
Depletion taken	-1,792,000
Impairment valuation loss	-4,001,000
Net book value at December 31	4,856,000
Producing Oil and Gas Properties Impaired in 2013 [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Net book value at January 1		13,180,000
Property additions		5,661,000
Depletion taken		-3,727,000
Impairment valuation loss		-1,373,000
Net book value at December 31		13,741,000
Non-Producing Oil and Gas Properties [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Impairment valuation loss	4,008,000	1,257,000	856,000
Capitalized costs for non producing oil and gas leasehold interests specified as percentage of total costs (in hundredths)	4.00%
Pecentage of interest in Kansas oil and gas properties sold (in hundredths)			50.00%
Proceeds from sale of oil and gas properties			578,000
Pre-tax gain on sale of oil and gas properties			475,000
South Texas Project acreage [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Total Non-producing Leasehold Costs	357,000	4,217,000
South Texas Project [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Proceeds from sale of oil and gas properties	1,509,000
Pre-tax gain on sale of oil and gas properties	632,000
West Texas Project [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Total Non-producing Leasehold Costs	0	116,000
Napoleonville Louisiana acreage [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Total Non-producing Leasehold Costs	48,000	162,000
Other Acreage Areas [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Net book value at January 1	411,000	329,000
Property additions	580,000	304,000
Property sale	0	0
Impairment valuation loss	-437,000	-222,000
Net book value at December 31	554,000	411,000
Total Non-producing Leasehold Costs	554,000	411,000
Other Oil and Gas Property [Member]
Fair value measurements for producing oil and gas properties that were subject to fair value impairment [Abstract]
Proceeds from sale of oil and gas properties	822,000
Pre-tax gain on sale of oil and gas properties	$747,000
Onshore Leasehold [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	3 years

Summary_of_Significant_Account4

Summary of Significant Accounting Policies, Derivatives by Hedging Relationship and Fair Value Measurements (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Company's asset retirement obligations [Roll Forward]
Balance on January 1,	$2,564,000	$1,886,000
Liabilities incurred	111,000	431,000
Accretion of discount	94,000	85,000
Liabilities settled	-305,000	-138,000
Revisions to estimates	0	300,000
Balance on December 31,	2,464,000	2,564,000
Escrow cash	75,000
Level 1 Quoted Prices [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Value	0	0
Factors impacting the change in the net value of the Company's fair value contracts [Abstract]
Net Fair Value January 1,	0	0
Net realized (gains) losses	0	0
Option gain	0
Option deposit		0
Option collateral	0
Net unrealized gains (losses)	0	0
Net Fair Value December 31,	0	0
Level 2 Observable [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Value	-7,000	395,000
Factors impacting the change in the net value of the Company's fair value contracts [Abstract]
Net Fair Value January 1,	395,000	-27,000
Net realized (gains) losses	220,000	27,000
Option gain	99,000
Option deposit		615,000
Option collateral	-714,000
Net unrealized gains (losses)	-7,000	-220,000
Net Fair Value December 31,	-7,000	395,000
Total Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Value	-7,000	395,000
Factors impacting the change in the net value of the Company's fair value contracts [Abstract]
Net Fair Value January 1,	395,000	-27,000
Net realized (gains) losses	220,000	27,000
Option gain	99,000
Option deposit		615,000
Option collateral	-714,000
Net unrealized gains (losses)	-7,000	-220,000
Net Fair Value December 31,	-7,000	395,000
Fair Value, Measurements, Recurring [Member] | Level 1 Quoted Prices [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives - Current assets	0	0
Derivatives - Current liabilities	0	0
Net Value	0	0
Factors impacting the change in the net value of the Company's fair value contracts [Abstract]
Net Fair Value December 31,	0	0
Fair Value, Measurements, Recurring [Member] | Level 2 Observable [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives - Current assets	1,332,000	449,000
Derivatives - Current liabilities	-1,339,000	-54,000
Net Value	-7,000	395,000
Factors impacting the change in the net value of the Company's fair value contracts [Abstract]
Net Fair Value December 31,	-7,000	395,000
Fair Value, Measurements, Recurring [Member] | Level 3 Unobservable [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives - Current assets	0	0
Derivatives - Current liabilities	0	0
Net Value	0	0
Factors impacting the change in the net value of the Company's fair value contracts [Abstract]
Net Fair Value December 31,	0	0
Fair Value, Measurements, Recurring [Member] | Counterparty Offsets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives - Current assets	-396,000	-54,000
Derivatives - Current liabilities	396,000	54,000
Net Value	0	0
Factors impacting the change in the net value of the Company's fair value contracts [Abstract]
Net Fair Value December 31,	0	0
Fair Value, Measurements, Recurring [Member] | Total Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives - Current assets	936,000	395,000
Derivatives - Current liabilities	-943,000	0
Net Value	-7,000	395,000
Factors impacting the change in the net value of the Company's fair value contracts [Abstract]
Net Fair Value December 31,	-7,000	395,000
Commodity Contract [Member] | Revenues - Marketing [Member] | Not Designated as Hedging Instrument [Member]
Earnings (loss) recognized in income [Abstract]
Gain (Loss)	$312,000	($193,000)	($1,365,000)

Income_Taxes_Details

Income Taxes (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current [Abstract]
Federal	($8,626)	($8,102)	($10,282)
State	-1,249	-892	-1,176
Current income tax (provision) benefit	-9,875	-8,994	-11,458
Deferred [Abstract]
Federal	5,878	-2,682	-4,940
State	273	-478	-438
Deferred income tax (provision) benefit	6,151	-3,160	-5,378
Income tax (provision) benefit	-3,724	-12,154	-16,836
Income tax (provision) benefit, continuing and discontinued operations [Abstract]
From continuing operations	-3,561	-12,429	-16,664
From discontinued operations	-163	275	-172
Income tax (provision) benefit	-3,724	-12,154	-16,836
Reconciliation of taxes computed at the corporate federal income tax rate to the reported income tax (provision) [Abstract]
Statutory federal income tax (provision) benefit	-3,587	-11,819	-15,619
State income tax (provision) benefit	-634	-891	-1,049
Federal statutory depletion	549	522	36
Other	-52	34	-204
Income tax (provision) benefit	-3,724	-12,154	-16,836
Current deferred tax asset (liability) [Abstract]
Allowance for doubtful accounts	62	424
Prepaid and other insurance	-719	-855
Fair value contracts	-1	73
Net current deferred liability	-658	-358
Long-term deferred tax asset (liability) [Abstract]
Property	-12,673	-18,964
Uniform capitalization	661	613
Other	-170	-283
Net long-term deferred tax liability	-12,182	-18,634
Net deferred tax liability	($12,840)	($18,992)
Federal [Member]
Income Tax Examination [Line Items]
Earliest Open Tax Year	2011
Texas [Member]
Income Tax Examination [Line Items]
Earliest Open Tax Year	2010
Louisiana [Member]
Income Tax Examination [Line Items]
Earliest Open Tax Year	2011
Michigan [Member]
Income Tax Examination [Line Items]
Earliest Open Tax Year	2011

Concentration_of_Credit_Risk_D

Concentration of Credit Risk (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Concentration Risk [Line Items]
Industry practice payment of receivables	20 days
Percentage of US demand supplied by company (in hundredths)	1.00%
Allowance for doubtful accounts	$179	$252
Changes in the allowance for doubtful accounts [Roll Forward]
Balance, beginning of year	252	206	357
Provisions for bad debts	50	147	0
Less: Write-offs and recoveries	-123	-101	-151
Balance, end of year	$179	$252	$206
Customer Concentration Risk [Member] | Minimum [Member]
Concentration Risk [Line Items]
Number of customers	3
Customer Concentration Risk [Member] | Maximum [Member]
Concentration Risk [Line Items]
Number of customers	5
Accounts Receivable [Member]
Concentration Risk [Line Items]
Number of customers	3	3	3
Accounts Receivable [Member] | Product Concentration Risk [Member]
Concentration Risk [Line Items]
Concentration risk, percentage (in hundredths)	90.00%
Accounts Receivable [Member] | Customer One [Member]
Concentration Risk [Line Items]
Concentration risk, percentage (in hundredths)	16.60%	16.00%	22.10%
Accounts Receivable [Member] | Customer Two [Member]
Concentration Risk [Line Items]
Concentration risk, percentage (in hundredths)	16.60%	15.80%	21.40%
Accounts Receivable [Member] | Customer Three [Member]
Concentration Risk [Line Items]
Concentration risk, percentage (in hundredths)	10.40%	12.70%	11.40%
Revenue [Member]
Concentration Risk [Line Items]
Number of customers	2	4	3
Revenue [Member] | Customer Concentration Risk [Member]
Concentration Risk [Line Items]
Concentration risk, percentage (in hundredths)	50.00%
Revenue [Member] | Customer One [Member]
Concentration Risk [Line Items]
Concentration risk, percentage (in hundredths)	20.30%	18.50%	20.20%
Revenue [Member] | Customer Two [Member]
Concentration Risk [Line Items]
Concentration risk, percentage (in hundredths)	14.00%	17.70%	17.90%
Revenue [Member] | Customer Three [Member]
Concentration Risk [Line Items]
Concentration risk, percentage (in hundredths)		15.80%	16.80%
Revenue [Member] | Customer Four [Member]
Concentration Risk [Line Items]
Concentration risk, percentage (in hundredths)		10.40%

Employee_Benefits_Details

Employee Benefits (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Employee Benefits [Abstract]
Contributory expenses by employer	$691,000	$674,000	$645,000

Transactions_with_Affiliates_D

Transactions with Affiliates (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Chairman and Chief Executive Officer, and Certain Family Partnerships and Affiliates [Member]
Related Party Transaction [Line Items]
Due to related parties, current	$51,000	$38,000
Expense reimbursements from related parties	151,000	152,000	152,000
Other Affiliated Entities [Member]
Related Party Transaction [Line Items]
Expense reimbursements from related parties	65,000	69,000	64,000
Expense reimbursements to related parties	42,000	99,000	98,000
Rent expense paid	607,000	481,000
Total study costs incurred	$70,420

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	Lawsuit
Commitments and Contingencies [Abstract]
Rental expense	$9,755,000	$8,281,000	$8,110,000
Commitments under long-term non-cancelable operating leases [Abstract]
2015	6,075,000
2016	6,118,000
2017	4,106,000
2018	1,666,000
2019	308,000
Thereafter	0
Estimated expenses and related liabilities for losses incurred not reported to insurance carrier	2,585,000	1,796,000
Accrued medical claims	1,057,000	1,129,000
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 2014	4,500,000
Minimum aggregate medical claims for umbrella insurance coverage for 2015	4,500,000
Number of suits alleging oil and gas production	1
Total number of lawsuits	3
Accrued future legal costs	$500,000	$200,000

Guarantees_Details

Guarantees (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Commodity Purchases [Member]
Parental guaranteed obligations [Abstract]
Commodity purchases, 2015	$41,110
Commodity purchases, 2016	0
Commodity purchases, 2017	0
Commodity purchases, 2018	0
Commodity purchases, Thereafter	0
Commodity purchases, Total	41,110
Letters of Credit [Member]
Parental guaranteed obligations [Abstract]
Letters of credit, 2015	15,300
Letters of credit, 2016	0
Letters of credit, 2017	0
Letters of credit, 2018	0
Letters of credit, Thereafter	0
Letters of credit, Total	15,300
Guarantor Obligation [Member]
Parental guaranteed obligations [Abstract]
Guaranteed obligations, 2015	56,410
Guaranteed obligations, 2016	0
Guaranteed obligations, 2017	0
Guaranteed obligations, 2018	0
Guaranteed obligations Thereafter	0
Guaranteed obligations, Total	$56,410

Segment_Reporting_Details

Segment Reporting (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Activities by segment [Abstract]
Revenues	$849,736,000	$1,173,970,000	$1,159,931,000	$949,189,000	$968,096,000	$1,060,340,000	$965,098,000	$952,435,000	$4,132,826,000		$3,945,969,000		$3,376,085,000
Segment Operating Earnings (loss)									18,094,000		43,436,000		52,766,000
Depreciation Depletion and Amortization									24,615,000		22,275,000		20,714,000
Inventory liquidation and valuation losses	14,247,000				3,824,000				14,247,000		3,824,000
Segment operating earnings [Abstract]
Segment operating earnings									18,094,000		43,436,000		52,766,000
General and administrative expenses									-8,613,000		-9,060,000		-8,810,000
Operating Earnings									9,481,000		34,376,000		43,956,000
Interest income									301,000		198,000		190,000
Interest expense									-2,000		-24,000		-10,000
Earnings from continuing operations before income taxes									9,780,000		34,550,000		44,136,000
Identifiable Assets By Segment [Abstract]
Assets	340,814,000				448,082,000				340,814,000		448,082,000
Reportable Segments [Member]
Activities by segment [Abstract]
Revenues									4,132,826,000		3,945,969,000		3,376,085,000
Segment Operating Earnings (loss)									18,094,000		43,436,000		52,766,000
Depreciation Depletion and Amortization									24,615,000		22,275,000		20,714,000
Property and Equipment Additions									30,523,000		27,602,000		51,012,000
Segment operating earnings [Abstract]
Segment operating earnings									18,094,000		43,436,000		52,766,000
Identifiable Assets By Segment [Abstract]
Assets	340,814,000				448,082,000				340,814,000		448,082,000		419,501,000
Marketing [Member]
Activities by segment [Abstract]
Inventory liquidation and valuation losses	14,247,000				3,824,000				14,247,000		3,824,000		1,596,000
Marketing [Member] | Reportable Segments [Member]
Activities by segment [Abstract]
Revenues									4,050,497,000		3,863,057,000		3,292,948,000
Segment Operating Earnings (loss)									20,854,000	[1]	40,369,000	[1]	46,145,000	[1]
Depreciation Depletion and Amortization									9,626,000		7,682,000		5,945,000
Property and Equipment Additions									13,598,000		11,343,000		12,391,000
Segment operating earnings [Abstract]
Segment operating earnings									20,854,000	[1]	40,369,000	[1]	46,145,000	[1]
Identifiable Assets By Segment [Abstract]
Assets	189,332,000				306,693,000				189,332,000		306,693,000		277,920,000
Transportation [Member] | Reportable Segments [Member]
Activities by segment [Abstract]
Revenues									68,968,000		68,783,000		67,183,000
Segment Operating Earnings (loss)									4,750,000		5,180,000		10,253,000
Depreciation Depletion and Amortization									7,416,000		7,099,000		5,921,000
Property and Equipment Additions									8,994,000		3,165,000		15,538,000
Segment operating earnings [Abstract]
Segment operating earnings									4,750,000		5,180,000		10,253,000
Identifiable Assets By Segment [Abstract]
Assets	37,643,000				34,406,000				37,643,000		34,406,000		38,940,000
Oil and Gas [Member]
Activities by segment [Abstract]
Gain on property sale									2,528,000				2,203,000
Property impairments									8,009,000		2,630,000		5,555,000
Oil and Gas [Member] | Reportable Segments [Member]
Activities by segment [Abstract]
Revenues									13,361,000		14,129,000		15,954,000
Segment Operating Earnings (loss)									-7,510,000	[2]	-2,113,000	[2]	-3,632,000	[2]
Depreciation Depletion and Amortization									7,573,000		7,494,000		8,848,000
Property and Equipment Additions									7,931,000		13,094,000		23,083,000
Segment operating earnings [Abstract]
Segment operating earnings									-7,510,000	[2]	-2,113,000	[2]	-3,632,000	[2]
Identifiable Assets By Segment [Abstract]
Assets	25,888,000				37,093,000				25,888,000		37,093,000		35,788,000
Cash and other [Member] | Reportable Segments [Member]
Identifiable Assets By Segment [Abstract]
Assets	$87,951,000				$69,890,000				$87,951,000		$69,890,000		$66,853,000
[1]	Marketing segment operating earnings included inventory liquidation and valuation losses totaling $14,247,000, $3,824,000 and $1,596,000 for 2014, 2013 and 2012, respectively.
[2]	Oil and gas segment operating earnings include gains on property sales totaling $2,528,000 and $2,203,000 during 2014 and 2012, respectively, and property impairments totaling $8,009,000, $2,630,000 and $5,555,000 for 2014, 2013 and 2012, respectively.

Discontinued_Operations_Detail

Discontinued Operations (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
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			808,000
Pre-tax earnings from discontinued operation	553,000
Refined Products Segment [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues from discontinued operations			25,717,000
Natural Gas Marketing Segment [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues from discontinued operations		2,377,000	4,879,000
Cash proceeds for sale	$664,000

Quarterly_Financial_Data_Unaud2

Quarterly Financial Data (Unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Selected quarterly financial data and earnings per share [Abstract]
Revenues	$849,736	$1,173,970	$1,159,931	$949,189	$968,096	$1,060,340	$965,098	$952,435	$4,132,826	$3,945,969	$3,376,085
Earnings from continuing operations	-6,974	3,855	3,975	5,363	289	7,238	6,521	8,073	6,219	22,121	27,472
Earnings from continuing operations, Per Share (in dollars per share)	($1.65)	$0.92	$0.94	$1.27	$0.06	$1.72	$1.55	$1.91	$1.48	$5.24	$6.51
Net Earnings (Loss), Amount	-6,670	3,855	3,975	5,363	109	7,156	6,330	8,015	6,523	21,610	27,791
Net Earnings (Loss), Per Share (in dollars per share)	($1.58)	$0.92	$0.94	$1.27	$0.02	$1.70	$1.50	$1.90	$1.55	$5.12	$6.59
Dividends	$927	$928	$928	$928	$928	$927	$928	$0	$3,711	$2,783	$2,615
Dividends, Per share (in dollars per share)	$0.22	$0.22	$0.22	$0.22	$0.22	$0.22	$0.22	$0	$0.88	$0.66

Oil_and_Gas_Producing_Activiti2

Oil and Gas Producing Activities (Unaudited) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property acquisition costs [Abstract]
Unproved	$1,144,000	$1,444,000	$1,965,000
Proved	0	0	0
Exploration costs [Abstract]
Expensed	5,054,000	1,619,000	1,151,000
Capitalized	0	0	0
Development costs	1,745,000	10,160,000	20,219,000
Total costs incurred	7,943,000	13,223,000	23,335,000
Capitalized costs relating to oil and gas producing activities [Abstract]
Unproved oil and gas properties	3,104,000	7,578,000
Proved oil and gas properties	85,557,000	91,369,000
Gross capitalized cost	88,661,000	98,947,000
Accumulated depreciation, depletion and amortization	-64,682,000	-64,169,000
Net capitalized cost	23,979,000	34,778,000
Components of proved oil and gas reserves [Abstract]
Period of average estimated price of proved reserves	12 months
Standardized measure of discounted future net cash flows [Abstract]
Future gross revenues	58,885,000	64,495,000	59,793,000
Future costs [Abstract]
Lease operating expenses	-16,421,000	-19,207,000	-16,357,000
Development costs	-1,068,000	-119,000	-299,000
Future net cash flows before income taxes	41,396,000	45,169,000	43,137,000
Discount at 10% per annum	-17,175,000	-17,729,000	-17,976,000
Discounted future net cash flows before income taxes	24,221,000	27,440,000	25,161,000
Future income taxes, net of discount at 10% per annum	-8,477,000	-9,604,000	-8,806,000
Standardized measure of discounted future net cash flows	15,744,000	17,836,000	16,355,000
Average Sales Price and Production Costs Per Unit of Production [Line Items]
Average domestic crude oil realized	54
Effect of income taxes and discounting on the standardized measure of discounted future net cash flows [Abstract]
Future net cash flows before income taxes	41,396,000	45,169,000	43,137,000
Future income taxes	-14,489,000	-15,809,000	-15,098,000
Future net cash flows	26,907,000	29,360,000	28,039,000
Discount at 10% per annum	-11,163,000	-11,524,000	-11,684,000
Standardized measure of discounted future net cash flows	15,744,000	17,836,000	16,355,000
Principal sources of changes in the standardized measure of discounted future net flows [Abstract]
Beginning of year	17,836,000	16,355,000	20,931,000
Sale of oil and gas reserves	-981,000	0	-3,802,000
Net change in prices and production costs	-72,000	9,341,000	-5,313,000
New field discoveries and extensions, net of future production costs	4,456,000	9,767,000	9,513,000
Sales of oil and gas produced, net of production costs	-6,590,000	-8,373,000	-8,953,000
Net change due to revisions in quantity estimates	2,460,000	-3,624,000	-940,000
Accretion of discount	1,773,000	1,797,000	1,944,000
Production rate changes and other	-4,265,000	-6,629,000	511,000
Net change in income taxes	1,127,000	-798,000	2,464,000
End of year	15,744,000	17,836,000	16,355,000
Results of operations for oil and gas producing activities [Abstract]
Revenues	13,361,000	14,129,000	15,954,000
Costs and expenses [Abstract]
Production	-6,771,000	-5,756,000	-7,091,000
Producing property impairment	-4,001,000	-1,373,000	-4,699,000
Exploration	-5,054,000	-1,619,000	-1,151,000
Oil and natural gas property sale gain	2,528,000	0	2,203,000
Depreciation, depletion and amortization	-7,573,000	-7,494,000	-8,848,000
Operating income (loss) before income taxes	-7,510,000	-2,113,000	-3,632,000
Income tax benefit	2,628,000	739,000	1,271,000
Operating income (loss)	($4,882,000)	($1,374,000)	($2,361,000)
Crude Oil [Member]
Average Sales Price and Production Costs Per Unit of Production [Line Items]
Average sales prices	89.6	94.99	93.85
Natural Gas [Member]
Average Sales Price and Production Costs Per Unit of Production [Line Items]
Average sales prices	5.42	4.69	3.51
Oil [Member]
Total proved reserves [Abstract]
Beginning of year	368,000	307,000	292,000
Revisions of previous estimates	6,000	-17,000	29,000
Oil and gas reserves sold	-11,000	0	-54,000
Extensions, discoveries and other reserve additions	82,000	180,000	138,000
Production	-127,000	-102,000	-98,000
End of year	318,000	368,000	307,000
Components of proved oil and gas reserves [Abstract]
Proved developed reserves	299,000	367,000	306,000
Proved undeveloped reserves	19,000	1,000	1,000
Total proved reserves	318,000	368,000	307,000
Natural Gas [Member]
Total proved reserves [Abstract]
Beginning of year	6,286,000	8,837,000	9,661,000
Revisions of previous estimates	724,000	-1,438,000	-507,000
Oil and gas reserves sold	-558,000	-28,000	-104,000
Extensions, discoveries and other reserve additions	292,000	523,000	2,395,000
Production	-1,133,000	-1,608,000	-2,608,000
End of year	5,611,000	6,286,000	8,837,000
Components of proved oil and gas reserves [Abstract]
Proved developed reserves	5,482,000	6,157,000	8,708,000
Proved undeveloped reserves	129,000	129,000	129,000
Total proved reserves	5,611,000	6,286,000	8,837,000