Adams Resources & Energy (AE) 10-K 6 Mar 20 2019 FY Annual report Financial data

Cover Page

Cover Page - USD ($)	12 Months Ended
	Dec. 31, 2019	Mar. 01, 2020	Jun. 28, 2019
Cover page.
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2019
Document Transition Report	false
Entity File Number	1-7908
Entity Registrant Name	ADAMS RESOURCES & ENERGY, INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	74-1753147
Entity Address, Address Line One	17 SOUTH BRIAR HOLLOW LANE
Entity Address, Address Line Two	SUITE 100
Entity Address, City or Town	HOUSTON
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77027
City Area Code	713
Local Phone Number	881-3600
Title of 12(b) Security	Common Stock, $0.10 Par Value
Trading Symbol	AE
Security Exchange Name	NYSEAMER
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 74,219,902
Entity Common Stock, Shares Outstanding		4,235,533
Documents Incorporated by Reference	Portions of the Proxy Statement for the Annual Meeting of Shareholders to be held May 6, 2020 are incorporated by reference into Part III of this annual report on Form 10-K.
Entity Central Index Key	0000002178
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Amendment Flag	false

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 112,994	$ 117,066
Restricted cash	9,261	0
Accounts receivable, net of allowance for doubtful accounts of $141 and $153, respectively	94,534	85,197
Accounts receivable – related party	0	425
Inventory	26,407	22,779
Derivative assets	0	162
Income tax receivable	2,569	2,404
Prepayments and other current assets	1,559	1,557
Total current assets	247,324	229,590
Property and equipment, net	69,046	44,623
Operating lease right-of-use assets, net	9,576
Intangible assets, net	1,597	0
Cash deposits and other assets	3,299	4,657
Total assets	330,842	278,870
Current liabilities:
Accounts payable	147,851	116,068
Accounts payable – related party	5	29
Derivative liabilities	0	139
Current portion of finance lease obligations	2,167	883
Operating lease liabilities	2,252
Other current liabilities	7,302	6,148
Total current liabilities	159,577	123,267
Other long-term liabilities:
Asset retirement obligations	1,573	1,525
Total long-term lease obligation	4,376	3,209
Operating lease liabilities	7,323
Deferred taxes and other liabilities	6,352	4,271
Total liabilities	179,201	132,272
Commitments and contingencies (Note 17)
Shareholders’ equity:
Preferred stock – $1.00 par value, 960,000 shares authorized, none outstanding	0	0
Common stock – $0.10 par value, 7,500,000 shares authorized, 4,235,533 and 4,217,596 shares outstanding, respectively	423	422
Contributed capital	12,778	11,948
Retained earnings	138,440	134,228
Total shareholders’ equity	151,641	146,598
Total liabilities and shareholders’ equity	$ 330,842	$ 278,870

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 141	$ 153
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 outstanding (in shares)	4,235,533	4,217,596

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenues:
Total revenues	$ 1,811,247	$ 1,750,213	$ 1,322,060
Costs and expenses:
Oil and natural gas property impairments	0	0	3
General and administrative	10,198	8,937	9,707
Depreciation, depletion and amortization	16,641	10,654	13,599
Total costs and expenses	1,803,447	1,748,805	1,320,558
Operating earnings	7,800	1,408	1,502
Other income (expense):
Loss on deconsolidation of subsidiary (Note 4)	0	0	(3,505)
Impairment of investment in unconsolidated affiliate (Note 4)	0	0	(2,500)
Gain on dissolution of investment (Note 4)	573	0	0
Interest income	2,766	2,155	1,103
Interest expense	(636)	(109)	(27)
Total other income (expense), net	2,703	2,046	(4,929)
(Losses) earnings before income taxes	10,503	3,454	(3,427)
Income tax (provision) benefit:
Current	(211)	427	(895)
Deferred	(2,085)	(936)	3,840
Income tax benefit (provision)	(2,296)	(509)	2,945
Net (losses) earnings	$ 8,207	$ 2,945	$ (482)
Earnings (losses) per share:
Basic net (losses) earnings per share (in dollars per share)	$ 1.94	$ 0.70	$ (0.11)
Diluted net (losses) earnings per common share (in dollars per share)	1.94	0.70	(0.11)
Dividends per common share (in dollars per share)	$ 0.94	$ 0.88	$ 0.88
Marketing
Revenues:
Total revenues	$ 1,748,056	$ 1,694,437	$ 1,267,275
Costs and expenses:
Cost and expenses	1,723,216	1,681,045	1,247,763
Transportation
Revenues:
Total revenues	63,191	55,776	53,358
Costs and expenses:
Cost and expenses	53,392	48,169	48,538
Oil and natural gas
Revenues:
Total revenues	0	0	1,427
Costs and expenses:
Cost and expenses	$ 0	$ 0	$ 948

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating activities:
Net (losses) earnings	$ 8,207	$ 2,945	$ (482)
Adjustments to reconcile net (losses) earnings to net cash provided by operating activities:
Depreciation, depletion and amortization	16,641	10,654	13,599
Gains on sales of property	(1,400)	(1,240)	(594)
Impairment of oil and natural gas properties	0	0	3
Provision for doubtful accounts	(12)	(150)	78
Stock-based compensation expense	478	255	0
Deferred income taxes	2,085	936	(3,840)
Net change in fair value contracts	23	(2)	27
Gain on dissolution of AREC	(573)	0	0
Impairment of investments in unconsolidated affiliates	0	0	2,500
Loss on deconsolidation of subsidiary	0	0	3,505
Changes in assets and liabilities:
Accounts receivable	(8,373)	36,350	(34,935)
Accounts receivable/payable, affiliates	(24)	24	271
Inventories	(3,628)	(10,587)	878
Income tax receivable	(165)	(1,087)	1,418
Prepayments and other current assets	(2)	(293)	831
Accounts payable	31,795	(10,252)	44,790
Accrued liabilities	1,154	1,744	(991)
Other	693	1,717	(962)
Net cash provided by operating activities	46,899	31,014	26,096
Investing activities:
Property and equipment additions	(35,743)	(11,731)	(2,644)
Asset acquisitions	(5,624)	(10,272)	0
Proceeds from property sales	3,680	2,038	720
Proceeds from sales of AREC assets	0	0	2,775
Proceeds from dissolution of AREC	998	0	0
Insurance and state collateral (deposits) refunds	652	830	(1,067)
Net cash used in investing activities	(36,037)	(19,135)	(216)
Financing activities:
Principal repayments of finance lease obligations	(1,697)	(495)	(118)
Dividends paid on common stock	(3,976)	(3,711)	(3,711)
Net cash used in financing activities	(5,673)	(4,206)	(3,829)
Increase in cash and cash equivalents, including restricted cash	5,189	7,673	22,051
Cash and cash equivalents, including restricted cash, at beginning of period	117,066	109,393	87,342
Cash and cash equivalents, including restricted cash, at end of period	$ 122,255	$ 117,066	$ 109,393

CONSOLIDATED STATEMENTS OF SHAR

CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY - USD ($) $ in Thousands	Total	Common Stock	Contributed Capital	Retained Earnings
Beginning balance at Dec. 31, 2016	$ 151,312	$ 422	$ 11,693	$ 139,197
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (losses) earnings	(482)			(482)
Dividends declared:
Common stock	(3,711)			(3,711)
Ending balance at Dec. 31, 2017	147,119	422	11,693	135,004
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (losses) earnings	2,945			2,945
Stock-based compensation expense	255		255
Dividends declared:
Common stock	(3,711)			(3,711)
Awards under LTIP	(10)			(10)
Ending balance at Dec. 31, 2018	146,598	422	11,948	134,228
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (losses) earnings	8,207			8,207
Stock-based compensation expense	478		478
Issuance of common shares for acquisition	392	1	391
Cancellation of shares withheld to cover taxes upon vesting of restricted awards	(39)		(39)
Dividends declared:
Common stock	(3,976)			(3,976)
Awards under LTIP	(19)			(19)
Ending balance at Dec. 31, 2019	$ 151,641	$ 423	$ 12,778	$ 138,440

CONSOLIDATED STATEMENTS OF SH_2

CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Statement of Stockholders' Equity [Abstract]
Dividends per common share (in dollars per share)	$ 0.94	$ 0.88
Awards under LTIP (in dollars per share)	$ 0.94	$ 0.44

Organization and Basis of Prese

Organization and Basis of Presentation	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	Organization and Basis of Presentation Organization Adams Resources & Energy, Inc. (“AE”) is a publicly traded Delaware corporation organized in 1973, the common shares of which are listed on the NYSE American LLC under the ticker symbol “AE”. We, through our subsidiaries, are primarily engaged in the business of crude oil marketing, transportation and storage in various crude oil and natural gas basins in the lower 48 states of the United States (“U.S.”). We also conduct tank truck transportation of liquid chemicals and dry bulk primarily in the lower 48 states of the U.S. with deliveries into Canada and Mexico, and with terminals in the Gulf Coast region of the U.S. Unless the context requires otherwise, references to “we,” “us,” “our,” the “Company” or “AE” are intended to mean the business and operations of Adams Resources & Energy, Inc. and its consolidated subsidiaries. On April 21, 2017, one of our wholly owned subsidiaries, Adams Resources Exploration Corporation (“AREC”), filed a voluntary petition in the United States Bankruptcy Court for the District of Delaware (the “Bankruptcy Court”) seeking relief under Chapter 11 of Title 11 of the United States Code (the “Bankruptcy Code”), Case No. 17-10866 (KG). AREC operated its business and managed its properties as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code and order of the Bankruptcy Court. AE was the primary creditor in the Chapter 11 process. On May 3, 2017, AREC filed a motion with the Bankruptcy Court for approval of an auction process to sell its assets pursuant to Section 363 of the Bankruptcy Code and for approval to engage an advisor to conduct the auction. The auction commenced on July 19, 2017 to determine the highest or otherwise best bid to acquire all or substantially all of AREC’s assets. During the third quarter of 2017, Bankruptcy Court approval was obtained on three asset purchase and sales agreements with three unaffiliated parties, and AREC closed on the sales of substantially all of its assets (see Note 4 for further information). As a result of AREC’s voluntary bankruptcy filing in April 2017, we no longer controlled the operations of AREC; therefore, we deconsolidated AREC effective with the bankruptcy filing and recorded our investment in AREC under the cost method (see Note 4 for further information). We obtained approval of a confirmed plan in December 2017, and the case was dismissed in October 2018. Over the past few years prior to the bankruptcy filing, we have de-emphasized our upstream operations and do not expect this Chapter 11 filing by AREC to have a material adverse impact on any of our core businesses. Historically, we have operated and reported in three business segments: (i) crude oil marketing, transportation and storage, (ii) tank truck transportation of liquid chemicals and dry bulk, and (iii) upstream crude oil and natural gas exploration and production. We exited the crude oil and natural gas exploration and production business during 2017 with the sale of our crude oil and natural gas exploration and production assets (see Note 4 for further information). The consolidated financial statements and the accompanying notes are prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) and the rules of the U.S. Securities and Exchange Commission (“SEC”). All significant intercompany transactions and balances have been eliminated in consolidation. Use of Estimates The preparation of our financial statements in conformity with GAAP requires management to use estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. We base our estimates and judgments on historical experience and on various other assumptions and information we believe to be reasonable under the circumstances. Estimates and assumptions about future events and their effects cannot be perceived with certainty and, accordingly, these estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as the operating environment changes. While we believe the estimates and assumptions used in the preparation of the consolidated financial statements are appropriate, actual results could differ from those estimates.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies We adhere to the following significant accounting policies in the preparation of our consolidated financial statements. Accounts Receivable and Allowance for Doubtful Accounts Accounts receivable associated with crude oil marketing activities comprise approximately 90 percent of our total receivables, and industry practice requires payment for these sales to occur within 20 days of the end of the month following a transaction. Our customer makeup, credit policies and the relatively short duration of receivables mitigate the uncertainty typically associated with receivables management. An allowance for doubtful accounts is provided where appropriate. Our allowance for doubtful accounts is determined based on specific identification combined with a review of the general status of the aging of all accounts. We consider the following factors in our review of our allowance for doubtful accounts: (i) historical experience with customers, (ii) the perceived financial stability of customers based on our research, (iii) the levels of credit we grant to customers, and (iv) the duration of the receivable. We may increase the allowance for doubtful accounts in response to the specific identification of customers involved in bankruptcy proceedings and similar financial difficulties. On a routine basis, we review estimates associated with the allowance for doubtful accounts to ensure that we have recorded sufficient reserves to cover potential losses. See Note 18 for further information regarding credit risk. The following table presents our allowance for doubtful accounts activity for the periods indicated (in thousands): December 31, 2019 2018 2017 Balance at beginning of period $ 153 $ 303 $ 225 Charges to costs and expenses 26 43 137 Deductions (38) (193) (59) Balance at end of period $ 141 $ 153 $ 303 Cash, Cash Equivalents and Restricted Cash Cash and cash equivalents represent unrestricted cash on hand and highly liquid investments with original maturities of less than three months from the date of purchase. Cash and cash equivalents are maintained with major financial institutions, and deposit amounts may exceed the amount of federally backed insurance provided. While we regularly monitor the financial stability of these institutions, cash and cash equivalents ultimately remain at risk subject to the financial viability of these institutions. Restricted cash represented an amount held in a segregated bank account by Wells Fargo as collateral for amounts outstanding under our letter of credit facility prior to its termination. In June 2019, the amount of outstanding letters of credit under our letter of credit facility exceeded the borrowing base as defined in the letter of credit facility agreement. As a result, we were required to deposit cash with the lender as security for the outstanding letters of credit. See “Letter of Credit Facility” within this Note 2 for further information. Our borrowing base was based on our net receivable balance, and due to customer prepayments, our borrowing base as outlined in the letter of credit facility did not fully support the outstanding letters of credit that had been issued. As a result, on July 1, 2019, we canceled the letter of credit facility, and secured the outstanding letters of credit with our restricted cash balance. The following table provides a reconciliation of cash and cash equivalents and restricted cash as reported in the consolidated balance sheets that totals to the amounts shown in the consolidated statements of cash flows (in thousands): December 31, 2019 2018 Cash and cash equivalents $ 112,994 $ 117,066 Restricted cash 9,261 — Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 122,255 $ 117,066 Common Shares Outstanding The following table reconciles our outstanding common stock for the periods indicated: Common shares Balance, December 31, 2017 and 2018 4,217,596 Issuance of shares in acquisition (see Note 7) 11,145 Vesting of restricted stock unit awards (see Note 14) 7,604 Shares withheld to cover taxes upon vesting of restricted stock unit awards (883) Other 71 Balance, December 31, 2019 4,235,533 Derivative Instruments In the normal course of our operations, our crude oil marketing segment purchases and sells crude oil. We seek to profit by procuring the commodity as it is produced and then delivering the product to the end users or the intermediate use marketplace. As typical for the industry, these 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, we account for these contracts at fair value, unless the normal purchase and sale exception is applicable. These types of underlying contracts are standard for the industry and are the governing document for our crude oil marketing segment. None of our derivative instruments have been designated as hedging instruments. Earnings Per Share Basic earnings (losses) per share is computed by dividing our net earnings (losses) by the weighted average number of shares of common stock outstanding during the period. Diluted earnings (losses) per share is computed by giving effect to all potential shares of common stock outstanding, including our stock related to unvested restricted stock unit awards. Unvested restricted stock unit awards granted under the Adams Resources & Energy, Inc. 2018 Long-Term Incentive Plan (“2018 LTIP”) are not considered to be participating securities as the holders of these shares do not have non-forfeitable dividend rights in the event of our declaration of a dividend for common shares (see Note 14 for further discussion). A reconciliation of the calculation of basic and diluted earnings (losses) per share was as follows for the periods indicated (in thousands, except per share data): Year Ended December 31, 2019 2018 2017 Earnings (losses) per share – numerator: Net (losses) earnings $ 8,207 $ 2,945 $ (482) Denominator: Basic weighted average number of shares outstanding 4,228 4,218 4,218 Basic earnings (losses) per share $ 1.94 $ 0.70 $ (0.11) Diluted earnings (losses) per share: Diluted weighted average number of shares outstanding: Common shares 4,228 4,218 4,218 Restricted stock unit awards (1) 5 — — Performance share unit awards (2) — — — Total 4,233 4,218 4,218 Diluted earnings (losses) per share $ 1.94 $ 0.70 $ (0.11) _______________ (1) The dilutive effect of restricted stock unit awards for the year ended December 31, 2018 is de minimis. (2) The dilutive effect of performance share awards are included in the calculation of diluted earnings per share when the performance share award performance conditions have been achieved. The performance conditions for the performance share unit awards granted in 2018 and 2019 were achieved as of December 31, 2018 and 2019, respectively. For the years ended December 31, 2019 and 2018, the effects of the performance share awards on earning per share were anti-dilutive. Employee Benefits We maintain a 401(k) savings plan for the benefit of our employees. We do not maintain any other pension or retirement plans. Our 401(k) plan contributory expenses were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Contributory expenses $ 1,117 $ 808 $ 734 Fair Value Measurements The carrying amounts reported in the consolidated balance sheets 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. Our fair value estimates are based on either (i) actual market data or (ii) assumptions that other market participants would use in pricing an asset or liability, including estimates of risk, in the principal market of the asset or liability at a specified measurement date. Recognized valuation techniques employ inputs such as contractual prices, quoted market prices or rates, operating costs, discount factors and business growth rates. These inputs may be either readily observable, corroborated by market data or generally unobservable. In developing our estimates of fair value, we endeavor to utilize the best information available and apply market-based data to the highest extent possible. Accordingly, we utilize valuation techniques (such as the market approach) that maximize the use of observable inputs and minimize the use of unobservable inputs. A three-tier hierarchy has been established that classifies fair value amounts recognized in the financial statements based on the observability of inputs used to estimate such fair values. The hierarchy considers fair value amounts based on observable inputs (Levels 1 and 2) to be more reliable and predictable than those based primarily on unobservable inputs (Level 3). At each balance sheet reporting date, we categorize our financial assets and liabilities using this hierarchy. The characteristics of the fair value amounts classified within each level of the hierarchy are described as follows: • Level 1 fair values are based on quoted prices, which are available in active markets for identical assets or liabilities as of the measurement date. Active markets are defined as those in which transactions for identical assets or liabilities occur with sufficient frequency so as to provide pricing information on an ongoing basis. For Level 1 valuation of marketable securities, we utilize market quotations provided by our primary financial institution. For the valuations of derivative financial instruments, we utilize the New York Mercantile Exchange (“NYMEX”) for certain commodity valuations. • Level 2 fair values are based on (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 fair values are based on unobservable market data inputs for assets or liabilities. Fair value contracts consist of derivative financial instruments and are recorded as either an asset or liability measured at its fair value. Changes in fair value are recognized immediately in earnings unless the derivatives qualify for, and we elect, cash flow hedge accounting. We had no contracts designated for hedge accounting during any of the current reporting periods (see Note 12 for further information). Fair value estimates are based on assumptions that market participants would use when pricing an asset or liability, and we use a fair value hierarchy of three levels that prioritizes the information used to develop those assumptions. Currently, for all items presented herein, we utilize a market approach to valuing our contracts. On a contract by contract, forward month by forward month basis, we obtain observable market data for valuing our contracts. The fair value hierarchy gives the highest priority to quoted prices in active markets and the lowest priority to unobservable data. Impairment Testing for Long-Lived Assets Long-lived assets (primarily property and equipment and intangible assets) are reviewed for impairment when events or changes in circumstances indicate that the carrying amount of these assets may not be recoverable. Long-lived assets with carrying values that are not expected to be recovered through future cash flows are written-down to their estimated fair values. The carrying value of a long-lived asset is deemed not recoverable if it exceeds the sum of undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the asset’s carrying value exceeds the sum of its undiscounted cash flows, a non-cash asset impairment charge equal to the excess of the asset’s carrying value over its estimated fair value is recorded. Fair value is defined as the price that would be received to sell an asset or be paid to transfer a liability in an orderly transaction between market participants at a specified measurement date. We measure fair value using market price indicators or, in the absence of such data, appropriate valuation techniques. See Note 12 for information regarding impairment charges related to long-lived assets. 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 such items and their respective tax basis (see Note 13 for further information). On December 22, 2017, the Tax Cut and Jobs Act was enacted into law resulting in a reduction in the federal corporate income tax rate from 35 percent to 21 percent for years beginning in 2018, which impacts our income tax provision or benefit. Inventory Inventory consists of crude oil held in storage tanks and at third-party pipelines as part of our crude oil marketing operations. Crude oil inventory is carried at the lower of cost or net realizable value. At the end of each reporting period, we assess the carrying value of our inventory and make adjustments necessary to reduce the carrying value to the applicable net realizable value. Any resulting adjustments are a component of marketing costs and expenses on our consolidated statements of operations. During the year ended December 31, 2018, we recorded a charge of $5.4 million related to the write-down of our crude oil inventory due to declines in prices. There were no charges recognized during the years ended December 31, 2019 and 2017. Letter of Credit Facility We maintained a Credit and Security Agreement with Wells Fargo Bank, National Association, to provide for the issuance of up to $60.0 million in stand-by letters of credit primarily used to support crude oil purchases within our crude oil marketing segment and for other purposes. Stand-by letters of credit were issued as needed and were canceled as the underlying purchase obligations were satisfied by cash payment when due. The issuance of stand-by letters of credit enabled us to avoid posting cash collateral when procuring crude oil supply. We used the letter of credit facility for letters of credit related to our insurance program. At December 31, 2018, we had $4.6 million of letters of credit outstanding under this facility. Our borrowing base was based on our net receivable balance, and due to customer prepayments, our borrowing base as outlined in the letter of credit facility did not fully support the outstanding letters of credit that have been issued. As a result, on July 1, 2019, we canceled the letter of credit facility, and secured the outstanding letters of credit with our restricted cash balance . No further performance obligations exist under the facility effective with its termination. Property and Equipment Property and equipment is recorded at cost. Expenditures for additions, improvements and other enhancements to property and equipment are capitalized, and minor replacements, maintenance and repairs that do not extend asset life or add value are charged to expense as incurred. When property and equipment assets are retired or otherwise disposed of, the related cost and accumulated depreciation is removed from the accounts and any resulting gain or loss is included in results of operations in operating costs and expenses for the respective period. Property and equipment, except for land, is depreciated using the straight-line method over the estimated average useful lives of two thirty-nine Asset retirement obligations (“AROs”) are legal obligations associated with the retirement of tangible long-lived assets that result from their acquisition, construction, development and/or normal operation. When an ARO is incurred, we record a liability for the ARO and capitalize an equal amount as an increase in the carrying value of the related long-lived asset. ARO amounts are measured at their estimated fair value using expected present value techniques. Over time, the ARO liability is accreted to its present value (through accretion expense), and the capitalized amount is depreciated over the remaining useful life of the related long-lived asset. We will incur a gain or loss to the extent that our ARO liabilities are not settled at their recorded amounts. See Note 6 for additional information regarding our property and equipment and AROs. Recent Accounting Pronouncements Measurement of Credit Losses on Financial Instruments . In June 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-13, which replaces the current incurred loss impairment method with a method that reflects expected credit losses on financial instruments. In November 2018, the FASB issued ASU 2018-19, which clarifies the scope of the standard in the amendments in ASU 2016-13. In May 2019, the FASB issued ASU 2019-05, which provides entities with an option to irrevocably elect the fair value option for certain financial instruments. The new standard is effective as of January 1, 2020, and we adopted this standard effective January 1, 2020. We do not believe the adoption of this standard will have a material impact on our consolidated financial statements or on our disclosures. Stock-Based Compensation

Revenue Recognition

Revenue Recognition	12 Months Ended
	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition Adoption of ASC 606 On January 1, 2018, we adopted ASC 606, Revenue from Contracts with Customers (“ASC 606”) and all related Accounting Standards Updates by applying the modified retrospective method to all contracts that were not completed on January 1, 2018. The modified retrospective approach required us to recognize the cumulative effect of initially applying the new standard as an adjustment to the opening balance of retained earnings on January 1, 2018. Comparative information has not been restated and continues to be reported under the historical accounting standards in effect for those periods. The adoption of the new revenue standard did not result in a cumulative effect adjustment to our retained earnings since there was no significant impact upon adoption of the new standard. There was also no material impact to revenues, or any other financial statement line items for the year ended December 31, 2018 as a result of applying ASC 606. We expect the impact of the adoption of ASC 606 to remain immaterial to our net earnings on an ongoing basis. Revenue Recognition The new revenue standard’s core principle is that a company will recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. The new revenue standard requires entities to recognize revenue through the application of a five-step model, which includes: identification of the contract; identification of the performance obligations; determination of the transaction price; allocation of the transaction price to the performance obligations; and recognition of revenue as the entity satisfies the performance obligations. Our revenues are primarily generated from the marketing, transportation and storage of crude oil and other related products and the tank truck transportation of liquid chemicals and dry bulk. A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account in ASC 606. To identify the performance obligations, we considered all of the products or services promised in the contracts with customers, whether explicitly stated or implied based on customary business practices. Revenue is recognized when, or as, each performance obligation is satisfied under terms of the contract. Payment is typically due in full within 30 days of the invoice date. For our crude oil marketing segment, most of our crude oil purchase and sale contracts qualify and are designated as non-trading activities, and we consider these contracts as normal purchases and sales activity. For normal purchases and sales, our 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, generally upon delivery of the product to the customer. Revenue is recognized based on the transaction price and the quantity delivered. The majority of our crude oil sales contracts have multiple distinct performance obligations as the promise to transfer the individual goods (e.g., barrels of crude oil) is separately identifiable from the other goods promised within the contracts. Our performance obligations are satisfied at a point in time. For normal sales arrangements, revenue is recognized in the month in which control of the physical product is transferred to the customer, generally upon delivery of the product to the customer. For our transportation segment, each sales order associated with our master transportation agreements is considered a distinct performance obligation. The performance obligations associated with this segment are satisfied over time as the goods and services are delivered. Practical Expedients In connection with our adoption of ASC 606, we reviewed our revenue contracts for impact upon adoption. For example, our revenue contracts often include promises to transfer various goods and services to a customer. Determining whether goods and services are considered distinct performance obligations that should be accounted for separately versus together will continue to require continual assessment. We also used practical expedients permitted by ASC 606 when applicable. These practical expedients included: • Applying the new guidance only to contracts that were not completed as of January 1, 2018; and • Not accounting for the effects of significant financing components if the company expects that the period between when the entity transfers a promised good or service to a customer and when the customer pays for that good or service will be one year or less. Contract Balances The timing of revenue recognition, billings and cash collections results in billed accounts receivable and customer advances and deposits (contract liabilities) on our consolidated balance sheet. Currently, we do not record any contract assets in our financial statements due to the timing of revenue recognized and when our customers are billed. Our crude oil marketing customers are generally billed monthly based on contractually agreed upon terms. However, we sometimes receive advances or deposits from customers before revenue is recognized, resulting in contract liabilities. These contract assets and liabilities, if any, are reported on our consolidated balance sheets at the end of each reporting period. Revenue Disaggregation The following table disaggregates our revenue by segment and by major source for the periods indicated (in thousands): Reporting Segments Marketing Transportation Total Year Ended December 31, 2019 Revenues from contracts with customers $ 1,555,393 $ 63,191 $ 1,618,584 Other (1) 192,663 — 192,663 Total revenues $ 1,748,056 $ 63,191 $ 1,811,247 Timing of revenue recognition: Goods transferred at a point in time $ 1,555,393 $ — $ 1,555,393 Services transferred over time — 63,191 63,191 Total revenues from contracts with customers $ 1,555,393 $ 63,191 $ 1,618,584 Year Ended December 31, 2018 Revenues from contracts with customers $ 1,580,997 $ 55,776 $ 1,636,773 Other (1) 113,440 — 113,440 Total revenues $ 1,694,437 $ 55,776 $ 1,750,213 Timing of revenue recognition: Goods transferred at a point in time $ 1,580,997 $ — $ 1,580,997 Services transferred over time — 55,776 55,776 Total revenues from contracts with customers $ 1,580,997 $ 55,776 $ 1,636,773 _______________ (1) Other crude oil marketing revenues are recognized under ASC 815, Derivatives and Hedging , and ASC 845, Nonmonetary Transactions – Purchases and Sales of Inventory with the Same Counterparty . Other Crude Oil Marketing Revenue Certain of the commodity purchase and sale contracts utilized by our crude oil marketing segment qualify as derivative instruments with certain specifically identified contracts also designated as trading activity. From the time of contract origination, these contracts are marked-to-market and recorded on a net revenue basis in the accompanying consolidated financial statements. Certain of our 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. These buy/sell arrangements are reflected on a net revenue basis in the accompanying consolidated financial statements. Reporting these crude oil contracts on a gross revenue basis would increase our reported revenues as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Revenue gross-up $ 859,091 $ 448,846 $ 203,095

Subsidiary Bankruptcy, Deconsol

Subsidiary Bankruptcy, Deconsolidation and Sale	12 Months Ended
	Dec. 31, 2019
Reorganizations [Abstract]
Subsidiary Bankruptcy, Deconsolidation and Sale	Subsidiary Bankruptcy, Deconsolidation and Sale Bankruptcy Filing, Deconsolidation and Sale On April 21, 2017, AREC filed a voluntary petition in the Bankruptcy Court seeking relief under the Bankruptcy Code. AREC operated its business and managed its properties as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code and order of the Bankruptcy Court. As a result of AREC’s bankruptcy filing, AE ceded its authority to the Bankruptcy Court, and AE management could not carry on AREC activities in the ordinary course of business without Bankruptcy Court approval. AE managed the day-to-day operations of AREC, but did not have discretion to make significant capital or operating budgetary changes or decisions or to purchase or sell significant assets, as AREC’s material decisions were subject to review and approval by the Bankruptcy Court. For these reasons, we concluded that AE lost control of AREC, and no longer had significant influence over AREC during the pendency of the bankruptcy. Therefore, we deconsolidated AREC effective with the filing of the Chapter 11 bankruptcy in April 2017. In order to deconsolidate AREC, the carrying values of the assets and liabilities of AREC were removed from our consolidated balance sheet as of April 30, 2017, and we recorded our investment in AREC at its estimated fair value of approximately $5.0 million. We determined the fair value of our investment based upon bids we received in an auction process (see Note 1 for further discussion). We also determined that the estimated fair value of our investment in AREC was expected to be lower than its net book value immediately prior to the deconsolidation. As a result, during the second quarter of 2017, we recorded a non-cash charge of approximately $1.6 million associated with the deconsolidation of AREC, which reflected the excess of the net assets of AREC over its estimated fair value based on the expected sales transaction price of approximately $5.0 million, net of estimated transaction costs. Subsequent to the deconsolidation of AREC, we accounted for our investment in AREC using the cost method of accounting because AE did not exercise significant influence over the operations of AREC due to the Chapter 11 filing. On August 1, 2017, a hearing was held before the Bankruptcy Court seeking approval of asset purchase and sales agreements under Section 363 of the Bankruptcy Code with three unaffiliated parties to purchase AREC’s crude oil and natural gas assets for aggregate cash proceeds of approximately $5.2 million. The Bankruptcy Court approved the asset purchase and sales agreements, and we sold these assets during the third quarter of 2017. In October 2017, AREC submitted its liquidation plan to the Bankruptcy Court for approval. In connection with the sales of these assets and submission of the liquidation plan, we recognized an additional loss of $1.9 million during the third quarter of 2017, which represented the difference between the proceeds we expected to be paid upon settlement of the bankruptcy, net of anticipated remaining closing costs identified as part of the liquidation plan, and the book value of our cost method investment. In December 2017, we received proceeds of approximately $2.8 million from AREC related to the settlement of a portion of the bankruptcy process. The bankruptcy case was dismissed during October 2018. During 2019, we received a cash payment from AREC totaling approximately $1.0 million, related to the final settlement of its bankruptcy and dissolution. Of the amount received, approximately $0.4 million was offset against a receivable that had been set up as of December 31, 2018, and $0.6 million was recorded as a gain in our consolidated statements of operations. DIP Financing – Related Party Relationship

Prepayments and Other Current A

Prepayments and Other Current Assets	12 Months Ended
	Dec. 31, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepayments and Other Current Assets	Prepayments and Other Current Assets The components of prepayments and other current assets were as follows at the dates indicated (in thousands): December 31, 2019 2018 Insurance premiums $ 473 $ 677 Rents, licenses and other 1,086 880 Total $ 1,559 $ 1,557

Property and Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Property and Equipment	Property and Equipment The historical costs of our property and equipment and related accumulated depreciation balances were as follows at the dates indicated (in thousands): Estimated Useful Life December 31, in Years 2019 2018 Tractors and trailers (1) 5 – 6 $ 115,693 $ 96,523 Field equipment (2) 2 – 5 25,094 20,725 Buildings 5 – 39 16,055 15,746 Office equipment 2 – 5 1,951 1,863 Land 1,790 1,790 Construction in progress 3,661 2,794 Total 164,244 139,441 Less accumulated depreciation (95,198) (94,818) Property and equipment, net $ 69,046 $ 44,623 ______________ (1) Amounts include tractors held under finance leases in our crude oil marketing segment. At December 31, 2019 and 2018, gross property and equipment associated with these assets held under finance leases were $5.5 million and $4.7 million, respectively. Accumulated amortization associated with these assets held under finance leases were $1.7 million and $0.7 million at December 31, 2019 and 2018, respectively (see Note 16 for further information). (2) 2019 amount includes a tank storage and throughput arrangement in our crude oil marketing segment held under a finance lease. Gross property and equipment associated with these assets held under a finance lease at December 31, 2019 was $3.3 million. Accumulated amortization associated with these assets held under a finance lease at December 31, 2019 was $0.7 million (see Note 16 for further information). Components of depreciation, depletion and amortization expense were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Depreciation, depletion and amortization, excluding amounts under finance leases $ 14,833 $ 10,112 $ 13,478 Amortization of property and equipment under finance leases 1,808 542 121 Total depreciation, depletion and amortization $ 16,641 $ 10,654 $ 13,599 Gains on Sales of Assets We sold certain used tractors, trailers and other equipment and recorded net pre-tax gains as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Gains on sales of used tractors, trailers and equipment $ 1,400 $ 1,240 $ 594 Asset Retirement Obligations We record AROs for the estimated retirement costs associated with certain tangible long-lived assets. The estimated fair value of AROs are recorded in the period in which they are incurred and the corresponding cost is 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. If the liability is settled for an amount other than the recorded amount, an increase or decrease to expense is recognized. The following table reflects a summary of our AROs for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 ARO liability at beginning of year $ 1,525 $ 1,273 $ 2,329 Liabilities incurred 17 252 18 Accretion of discount 48 36 58 Liabilities settled (17) (36) (261) Deconsolidation of subsidiary (1) — — (871) ARO liability at end of year $ 1,573 $ 1,525 $ 1,273 _______________

Asset Acquisition

Asset Acquisition	12 Months Ended
	Dec. 31, 2019
Asset Acquisition [Abstract]
Asset Acquisition	Asset Acquisitions EH Transport On April 10, 2019, we entered into a purchase and sale agreement with EH Transport, Inc. and affiliates (collectively, “EH Transport”), a Houston, Texas based bulk carrier trucking company, for the purchase of certain transportation assets. On May 6, 2019, we closed on the asset acquisition for approximately $6.4 million, which consisted of $5.6 million in cash after post-closing adjustments related to equipment qualifications, 11,145 of our common shares valued at $0.4 million and contingent consideration valued at approximately $0.4 million. This acquisition added approximately 39 tractors and 51 trailers to our existing transportation fleet, and these assets were included in our transportation segment. This acquisition added new customers and new product lines to our transportation segment portfolio, which allows us to grow into new markets. As a result of the acquisition, in addition to general chemical products, we transport liquefied petroleum gas, asphalt and bleach for customers. We incurred approximately $0.1 million of acquisition costs in connection with this acquisition, which has been included in the allocation of the purchase price to the assets acquired. The following table summarizes the consideration paid for the EH Transport assets and the estimated fair value of the assets acquired at the acquisition date (in thousands): Consideration: Cash $ 5,624 Value of AE common shares issued 392 Contingent consideration arrangement 431 Fair value of total consideration transferred $ 6,447 Recognized amounts of identifiable assets acquired: Property and equipment — tractors and trailers $ 4,576 Shop, office and telecommunication equipment 20 Intangible assets — customer relationships 1,851 Total purchase price $ 6,447 The fair market value of the common shares issued in this transaction was determined based upon the closing share price of AE common stock on May 6, 2019 of $35.15. We assumed no liabilities in this acquisition. The estimated fair value of the acquired property and equipment was determined using the estimated market value of each type of asset. The estimated fair value of the acquired customer relationship intangible assets was determined using an income approach, specifically a discounted cash flow analysis. The income approach estimates the future benefits of the customer relationships and deducts the expenses incurred in servicing the relationships and the contributions from the other business assets to derive the future net benefits of these assets. The future net benefits are discounted back to present value using the appropriate discount rate, which results in the value of the customer relationships. A customer relationship intangible asset is the relationship between EH Transport and various customers to whom we did not have a previous relationship. The customer relationships we acquired in this transaction provide us with access to those customers to whom we did not have a previous relationship and allows us to enter product markets in which we had not previously participated. Because of the highly competitive and fragmented transportation market, we believe access to these customers and product lines will provide us with an entry into new markets. The discounted cash flow analysis used to estimate the fair value of the EH Transport customer relationships relied on Level 3 fair value inputs. Level 3 fair values are based on unobservable inputs. Unobservable inputs are used to measure fair value to the extent that observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset at the measurement date. With respect to the EH Transport customer relationships, the Level 3 inputs include the rate of retention of the current customers of EH Transport as of the valuation date, our transportation segment’s historical customer retention rate and projected future revenues associated with the customers. The EH Transport customers expected to remain with us after the transaction were included in the valuation of the customer relationships. We are amortizing the customer relationship intangible assets over a period of seven years, using a modified straight-line approach. During the year ended December 31, 2019, we recorded $0.2 million of amortization expense related to these intangible assets. The following table presents our forecast of amortization expense associated with these intangible assets for the years indicated (in thousands): 2020 2021 2022 2023 2024 Amortization expense $ 302 $ 283 $ 263 $ 244 $ 227 The purchase and sale agreement includes a contingent consideration arrangement that requires us to pay the former owner of the assets up to a quarterly maximum amount of $146,875 (undiscounted) plus interest for the first four quarters following the closing date of the acquisition. The amount to be paid is based upon the number of qualified truck drivers that are employed by us at the end of each quarter. The potential undiscounted amount of all future payments that could be required to be paid under the contingent consideration arrangement is between $0 and $587,500. The fair value of the contingent consideration arrangement of $0.4 million was estimated by applying an income valuation approach, which is based on Level 3 inputs, including the number of qualified truck drivers we expect will be employed at each payment date. At December 31, 2019, we had a remaining accrual of $0.2 million related to this contingent consideration arrangement, which was included in other current liabilities. Red River On October 1, 2018, we completed the purchase of a trucking company for $10.0 million that owned approximately 113 tractors and 126 trailers operating in the Red River area in North Texas and South Central Oklahoma. This acquisition was included in our crude oil marketing segment from the date of the acquisition. We incurred approximately $0.3 million of acquisition costs in connection with this acquisition, which was included in the allocation of the purchase price to the assets acquired. The purchase price of approximately $10.3 million was allocated on October 1, 2018 as follows (in thousands): Tractors $ 4,799 Trailers 4,901 Field equipment 381 Materials and supplies 191 Total purchase price $ 10,272

Cash Deposits and Other Assets

Cash Deposits and Other Assets	12 Months Ended
	Dec. 31, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Cash Deposits and Other Assets	Cash Deposits and Other Assets Components of cash deposits and other assets were as follows at the dates indicated (in thousands): December 31, 2019 2018 Amounts associated with liability insurance program: Insurance collateral deposits $ 1,233 $ 1,453 Excess loss fund 943 1,916 Accumulated interest income 609 788 Other amounts: State collateral deposits 37 57 Materials and supplies 477 443 Total $ 3,299 $ 4,657

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	12 Months Ended
	Dec. 31, 2019
Equity Method Investments and Joint Ventures [Abstract]
Investments in Unconsolidated Affiliates	Investments in Unconsolidated Affiliates At December 31, 2019, we had no remaining balances in our medical-related investments. We currently do not have any plans to pursue additional medical-related investments. Bencap In December 2015, we formed a new wholly owned subsidiary, Adams Resources Medical Management, Inc. (“ARMM”), and in January 2016, ARMM acquired a 30 percent member interest in Bencap LLC (“Bencap”) for a $2.2 million cash payment. Bencap provides medical insurance brokerage and medical claims auditing services to employers utilizing ERISA governed employee benefit plans. We accounted for this investment under the equity method of accounting. Under the terms of the investment agreement, Bencap had the option to request borrowings from us of up to $1.5 million (on or after December 5, 2016 but before October 31, 2018) that we were required to provide or forfeit our 30 percent member interest. During 2016, we determined that we were unlikely to provide additional funding due to Bencap’s lower than projected revenue growth and operating losses since investment inception. We completed a review of our equity method investment in Bencap during 2016 and determined that there was an other than temporary impairment. During 2016, we recognized an after-tax net loss of $1.4 million to write-off our investment in Bencap, which consisted of a pre-tax impairment charge of approximately $1.7 million, pre-tax losses from the equity method investment of $0.5 million and an income tax benefit of $0.8 million. In February 2017, in accordance with the terms of the investment agreement, Bencap requested additional funding of approximately $0.5 million from us. We declined the additional funding request and as a result, forfeited our 30 percent member interest in Bencap. At December 31, 2019, we had no further ownership interest in Bencap. VestaCare In April 2016, ARMM acquired an approximate 15 percent equity interest (less than 3 percent voting interest) in VestaCare, Inc., a California corporation (“VestaCare”), for a $2.5 million cash payment. VestaCare provides an array of software as a service (SaaS) electronic payment technologies to medical providers, payers and patients including VestaCare’s most recent product offering, VestaPay™. VestaPay™ allows medical care providers to structure fully automated and dynamically updating electronic payment plans for their patients. We account for this investment under the cost method of accounting. During 2017, we reviewed our investment in VestaCare and determined that the current projected operating results did not support the carrying value of the investment. As a result, during the third quarter of 2017, we recognized an impairment charge of $2.5 million to write-off our investment in VestaCare. At December 31, 2019, we continue to own an approximate 15 percent equity interest in VestaCare. AREC As a result of AREC’s voluntary bankruptcy filing in April 2017 and our loss of control of this subsidiary, we deconsolidated AREC in April 2017, and we recorded our investment in this subsidiary under the cost method of accounting. During the second quarter of 2017, we recorded a non-cash charge of approximately $1.6 million associated with the deconsolidation of AREC, which reflected the excess of the net assets of AREC over its estimated fair value based on the expected sales transaction price, net of estimated transaction costs. During the third quarter of 2017, as a result of the sale of substantially all of AREC’s assets, we recognized an additional loss of $1.9 million, which represented the difference between the net proceeds we expected to be paid upon settlement of the bankruptcy, net of anticipated remaining closing costs identified as part of the liquidation plan, and the book value of our cost method investment. In December 2017, we received proceeds of approximately $2.8 million from AREC related to the settlement of a portion of the bankruptcy process. The bankruptcy case was dismissed during October 2018. During 2019, we received a cash payment from AREC totaling approximately $1.0 million, related to the final settlement of its bankruptcy and dissolution. Of the amount received, approximately $0.4 million was offset against a receivable that had been set up as of December 31, 2018, and $0.6 million was recorded as a gain in our consolidated statements of operations.

Segment Reporting

Segment Reporting	12 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Segment Reporting	Segment Reporting Historically, our three reporting segments have been: (i) crude oil marketing, transportation and storage, (ii) tank truck transportation of liquid chemicals and dry bulk, and (iii) upstream crude oil and natural gas exploration and production. Our upstream crude oil and natural gas exploration and production wholly owned subsidiary filed for bankruptcy in April 2017 (see Note 4 for further information), and as a result of our loss of control of the wholly owned subsidiary, AREC was deconsolidated and was accounted for under the cost method of accounting. AREC remained a reportable segment until its deconsolidation, effective April 30, 2017. Financial information by reporting segment was as follows for the periods indicated (in thousands): Reporting Segments Marketing Transportation Oil and Gas and Other (1) Total Year Ended December 31, 2019 Revenues $ 1,748,056 $ 63,191 $ — $ 1,811,247 Segment operating (losses) earnings (2) 16,099 1,899 — 17,998 Depreciation, depletion and amortization 8,741 7,900 — 16,641 Property and equipment additions (4) 7,249 28,472 22 35,743 Year Ended December 31, 2018 Revenues $ 1,694,437 $ 55,776 $ — $ 1,750,213 Segment operating (losses) earnings (2) 7,008 3,337 — 10,345 Depreciation, depletion and amortization 6,384 4,270 — 10,654 Property and equipment additions (4) (5) 1,540 10,178 13 11,731 Year Ended December 31, 2017 Revenues $ 1,267,275 $ 53,358 $ 1,427 $ 1,322,060 Segment operating (losses) earnings (2) (3) 11,700 (544) 53 11,209 Depreciation, depletion and amortization 7,812 5,364 423 13,599 Property and equipment additions 468 351 1,825 2,644 _________________ (1) Amounts presented for the year ended December 31, 2017 are related to our upstream crude oil and natural gas exploration and production segment prior to its deconsolidation. (2) Our crude oil marketing segment’s operating earnings included inventory liquidation gains of $3.7 million and $3.3 million, respectively, for the years ended December 31, 2019 and 2017, and inventory valuation losses of $5.4 million for the year ended December 31, 2018. (3) Segment operating (losses) earnings for the year ended December 31, 2017 includes approximately $0.4 million of costs related to a voluntary early retirement program that was implemented in August 2017. (4) Our crude oil marketing segment’s property and equipment additions do not include approximately $4.1 million, $2.9 million and $1.8 million of assets acquired under finance leases during the years ended December 31, 2019, 2018 and 2017, respectively. See Note 16 for further information. (5) During the years ended December 31, 2019 and 2018, we had $22 thousand and $13 thousand, respectively, of property and equipment additions for leasehold improvements at our corporate headquarters, which is not attributed or allocated to any of our reporting segments. Segment operating earnings reflect revenues net of operating costs and depreciation, depletion and amortization expense and are reconciled to earnings (losses) before income taxes, as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Segment operating earnings $ 17,998 $ 10,345 $ 11,209 General and administrative (1) (10,198) (8,937) (9,707) Operating earnings 7,800 1,408 1,502 Loss on deconsolidation of subsidiary — — (3,505) Impairment of investment in unconsolidated affiliate — — (2,500) Gain on dissolution of investment 573 — — Interest income 2,766 2,155 1,103 Interest expense (636) (109) (27) (Losses) earnings before income taxes $ 10,503 $ 3,454 $ (3,427) _______________ (1) General and administrative expenses for the year ended December 31, 2017 included approximately $1.0 million of costs related to a voluntary early retirement program we implemented in August 2017. Identifiable assets by industry segment were as follows at the dates indicated (in thousands): December 31, 2019 2018 2017 Reporting segment: Marketing $ 141,402 $ 119,370 $ 134,745 Transportation 58,483 34,112 29,069 Oil and Gas (1) — — 425 Cash and other 130,957 125,388 118,465 Total assets $ 330,842 $ 278,870 $ 282,704 ____________________ (1) At December 31, 2017, amount represents our remaining cost method investment in this segment. See Note 4 for further information. There were no intersegment sales during the years ended December 31, 2019 and 2018, and intersegment sales during the year ended December 31, 2017 were insignificant. Other identifiable assets are primarily corporate cash, corporate accounts receivable and properties not identified with any specific segment of our business. Accounting policies for transactions between reportable segments are consistent with applicable accounting policies as disclosed herein.

Transactions with Affiliates

Transactions with Affiliates	12 Months Ended
	Dec. 31, 2019
Related Party Transactions [Abstract]
Transactions with Affiliates	Transactions with Affiliates We enter into certain transactions in the normal course of business with affiliated entities including direct cost reimbursement for shared phone and administrative services. In addition, we lease our corporate office space in a building operated by 17 South Briar Hollow Lane, LLC, an affiliate of KSA Industries, Inc., which is an affiliated entity. We utilized our former affiliate, Bencap, to administer certain of our employee medical benefit programs including a detail audit of individual medical claims (see Note 9 for further information). Bencap earned a fee from us for providing these services at a discounted amount from its standard charge to non-affiliates. We had an equity method investment in Bencap, which was forfeited during the first quarter of 2017. As a result, we have no further ownership interest in Bencap (see Note 9). Activities with affiliates were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Affiliate billings to us $ 83 $ 75 $ 81 Billings to affiliates 5 6 4 Rentals paid to affiliate 487 487 583 Fee paid to Bencap (1) — — 108 ___________________ (1) Amount represents fees paid to Bencap through the forfeiture of our investment during the first quarter of 2017. As a result of the investment forfeiture, Bencap is no longer an affiliate. DIP Financing

Derivative Instruments and Fair

Derivative Instruments and Fair Value Measurements	12 Months Ended
	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Fair Value Measurements	Derivative Instruments and Fair Value Measurements Derivative Instruments At December 31, 2019, we had in place six commodity purchase and sale contracts with no fair value associated with them as the contractual prices of crude oil were within the range of prices specified in the agreements. These commodity purchase and sale contracts encompassed approximately: • 258 barrels per day of crude oil during January 2020 through February 2020; • 322 barrels per day of crude oil during March 2020 through April 2020; and • 258 barrels per day of crude oil during May 2020 through December 2020. At December 31, 2018, we had in place ten commodity purchase and sale contracts with fair value associated with them as the contractual prices of crude oil were outside of the range of prices specified in the agreements. These commodity purchase and sale contracts encompassed approximately: • 322 barrels per day of crude oil during January 2019 through April 2019; • 258 barrels per day of crude oil during May 2019; • 322 barrels per day of crude oil during June 2019 through August 2019; and • 258 barrels per day of crude oil during September 2019 through December 2019. The estimated fair value of forward month commodity contracts (derivatives) reflected in the accompanying consolidated balance sheets were as follows at the dates indicated (in thousands): Balance Sheet Location and Amount Current Other Current Other December 31, 2019 Assets Assets Liabilities Liabilities Asset derivatives: Fair value forward hydrocarbon commodity contracts at gross valuation $ — $ — $ — $ — Liability derivatives: Fair value forward hydrocarbon commodity contracts at gross valuation — — — — Less counterparty offsets — — — — As reported fair value contracts $ — $ — $ — $ — December 31, 2018 Asset derivatives: Fair value forward hydrocarbon commodity contracts at gross valuation $ 162 $ — $ — $ — Liability derivatives: Fair value forward hydrocarbon commodity contracts at gross valuation — — 139 — Less counterparty offsets — — — — As reported fair value contracts $ 162 $ — $ 139 $ — We only enter into commodity contracts with creditworthy counterparties and evaluate our exposure to significant counterparties on an ongoing basis. At December 31, 2019 and 2018, we were not holding nor have we posted any collateral to support our forward month fair value derivative activity. We are not subject to any credit-risk related trigger events. We have no other financial investment arrangements that would serve to offset our derivative contracts. Forward month commodity contracts (derivatives) reflected in the accompanying consolidated statements of operations were as follows for the periods indicated (in thousands): Gains (Losses) Year Ended December 31, 2019 2018 2017 Revenues – marketing $ (24) $ 2 $ (26) Fair Value Measurements The following table reflects, by level with the Level 1, 2 and 3 fair value hierarchy, the carrying values of our financial assets and liabilities at the dates indicated (in thousands): Fair Value Measurements Using Quoted Prices in Active Significant Markets for Other Significant Identical Assets Observable Unobservable and Liabilities Inputs Inputs Counterparty (Level 1) (Level 2) (Level 3) Offsets Total December 31, 2019 Derivatives: Current assets $ — $ — $ — $ — $ — Current liabilities — — — — — Net value $ — $ — $ — $ — $ — December 31, 2018 Derivatives: Current assets $ — $ 162 $ — $ — $ 162 Current liabilities — (139) — — (139) Net value $ — $ 23 $ — $ — $ 23 These assets and liabilities are measured on a recurring basis and are classified based on the lowest level of input used to estimate their fair value. Our assessment of the relative significance of these inputs requires judgments. When determining fair value measurements, we make credit valuation adjustments to reflect both our own nonperformance risk and our counterparty’s nonperformance risk. When adjusting the fair value of derivative contracts for the effect of nonperformance risk, we consider the impact of netting and any applicable credit enhancements. Credit valuation adjustments utilize Level 3 inputs, such as credit scores to evaluate the likelihood of default by us or our counterparties. At December 31, 2019 and 2018, credit valuation adjustments were not significant to the overall valuation of our fair value contracts. As a result, applicable fair value assets and liabilities are included in their entirety in the fair value hierarchy. Nonrecurring Fair Value Measurements Certain nonfinancial assets and liabilities are measured at fair value on a nonrecurring basis and are subject to fair value adjustments in certain circumstances, such as when there is evidence of impairment. During the years ended December 31, 2019 and 2018, we had no long-lived assets that were subject to non-recurring fair value measurements. The following table presents categories of long-lived assets that were subject to non-recurring fair value measurements during the year ended December 31, 2017 (in thousands): Fair Value Measurements at the End of the Reporting Period Using Quoted Prices in Active Significant Carrying Markets for Other Significant Total Value at Identical Assets Observable Unobservable Non-Cash December 31, and Liabilities Inputs Inputs Impairment 2017 (Level 1) (Level 2) (Level 3) Loss Oil and gas properties — Investment in AREC $ 425 $ — $ 425 $ — $ 3,505 Investment in VestaCare — — — — 2,500 $ 6,005

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The components of our income tax (provision) benefit were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Current: Federal $ 164 $ 388 $ (1,418) State (375) 39 523 Total current (211) 427 (895) Deferred: Federal (2,063) (752) 3,722 State (22) (184) 118 Total deferred (2,085) (936) 3,840 Total (provision for) benefit from income taxes $ (2,296) $ (509) $ 2,945 A reconciliation of the (provision for) benefit from income taxes with amounts determined by applying the statutory U.S. federal income tax rate to income before income taxes was as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Pre-tax net book income (loss) $ 10,503 $ 3,454 $ (3,427) Statutory federal income tax (provision) benefit $ (2,206) $ (725) $ 1,165 State income tax (provision) benefit (397) (145) 736 Federal statutory depletion — — 153 Federal tax rate adjustment — — 2,007 Valuation allowance — — (1,038) Reverse valuation allowance — 98 — Return to provision adjustments 285 388 — Other 22 (125) (78) Total (provision for) benefit from income taxes $ (2,296) $ (509) $ 2,945 Effective income tax rate (1) (2) 22 % 15 % 86 % _______________ (1) Excluding the adjustment related to the federal tax rate change, the effective income tax rate for 2018 is 26 percent. (2) Excluding the adjustment related to the return to provision, the effective income tax rate for 2017 is 58 percent. Deferred income taxes reflect the net difference between the financial statement carrying amounts and the underlying income tax basis in these items. The components of the federal deferred tax asset (liability) were as follows at the dates indicated (in thousands): December 31, 2019 2018 Long-term deferred tax asset (liability): Prepaid and other insurance $ 248 $ (170) Property (9,953) (5,259) Investments in unconsolidated affiliates 525 525 Valuation allowance related to investments in unconsolidated affiliates (525) (525) Net operating loss 3,567 1,436 Other (184) (245) Net long-term deferred tax liability (6,322) (4,238) Net deferred tax liability $ (6,322) $ (4,238) 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. We have 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 2015 Texas 2015 Louisiana 2016 Michigan 2015 Other Matters

Share-Based Compensation Plan

Share-Based Compensation Plan	12 Months Ended
	Dec. 31, 2019
Share-based Payment Arrangement [Abstract]
Share-Based Compensation Plan	Stock-Based Compensation Plan In May 2018, our shareholders approved the 2018 LTIP, a long-term incentive plan under which any employee or non-employee director who provides services to us is eligible to participate in the plan. The 2018 LTIP, which is overseen by the Compensation Committee of our Board of Directors, provides for the grant of various types of equity awards, of which restricted stock unit awards and performance-based compensation awards have been granted. The maximum number of shares authorized for issuance under the 2018 LTIP is 150,000 shares, and the 2018 LTIP is effective until May 8, 2028. We began awarding stock-based compensation to eligible employees and directors in June 2018. After giving effect to awards granted under the 2018 LTIP, forfeitures under the 2018 LTIP and achievement of performance factors through December 31, 2019, a total of 120,827 shares were available for issuance. Compensation expense recognized in connection with equity-based awards was as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Compensation expense $ 478 $ 255 $ — If dividends are paid with respect to our common shares during the vesting period, an equivalent amount will accrue and be held by us without interest until the restricted stock unit awards and performance share unit awards vest, at which time the amount will be paid to the recipient. If the award is forfeited prior to vesting, the accrued dividends will also be forfeited. At December 31, 2019 and 2018, we had $23,600 and $9,500, respectively, of accrued dividend amounts for awards granted under the 2018 LTIP. Restricted Stock Unit Awards A restricted stock unit award is a grant of a right to receive our common shares in the future at no cost to the recipient apart from fulfilling service and other conditions once a defined vesting period expires, subject to customary forfeiture provisions. A restricted stock unit award will either be settled by the delivery of common shares or by the payment of cash based upon the fair market value of a specified number of shares, at the discretion of the Compensation Committee, subject to the terms of the applicable award agreement. The Compensation Committee intends for these awards to vest with the settlement of common shares. Restricted stock unit awards generally vest at a rate of approximately 33 percent per year beginning one year after the grant date and are non-vested until the required service periods expire. The fair value of a restricted stock unit award is based on the market price per share of our common shares on the date of grant. Compensation expense is recognized based on the grant date fair value over the requisite service or vesting period. The following table presents restricted stock unit award activity for the periods indicated: Weighted- Average Grant Number of Date Fair Value Shares per Share (1) Restricted stock unit awards at January 1, 2018 — $ — Granted (2) 13,733 $ 43.00 Vested — $ — Forfeited — $ — Restricted stock unit awards at December 31, 2018 13,733 Granted (3) 14,376 $ 34.00 Vested (7,188) $ 41.90 Forfeited (2,139) $ 38.42 Restricted stock unit awards at December 31, 2019 18,782 ____________________ (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued. (2) The aggregate grant date fair value of restricted stock unit awards issued during 2018 was $0.6 million based on a grant date market price of our common shares of $43.00 per share. (3) The aggregate grant date fair value of restricted stock unit awards issued during 2019 was $0.5 million based on a grant date market price of our common shares of $34.00 per share. Unrecognized compensation cost associated with restricted stock unit awards was approximately $0.3 million at December 31, 2019. Due to the graded vesting provisions of these awards, we expect to recognize the remaining compensation cost for these awards over a weighted-average period of 1.4 years. Performance Share Unit Awards An award granted as performance-based compensation is awarded to a participant contingent upon attainment of our future performance goals during a performance cycle. Performance goals are pre-established by the Compensation Committee. Following the end of the performance period, the holder of a performance-based compensation award is entitled to receive payment of an amount not exceeding the number of shares of common stock subject to, or the maximum value of, the performance-based compensation award, based on the achievement of the performance measures for the performance period. The performance share unit awards generally vest in full approximately three The fair value of a performance share unit award is based on the market price per share of our common shares on the date of grant. Compensation expense is recognized based on the grant date fair value over the requisite service or vesting period. Compensation expense is generally adjusted for the performance goals on a quarterly basis. The following table presents performance share unit award activity for the periods indicated: Weighted- Average Grant Number of Date Fair Value Shares per Share (1) Performance share unit awards at January 1, 2018 — $ — Granted (2) 7,932 $ 43.00 Performance factor decrease (3) (3,966) $ 43.00 Vested — $ — Forfeited — $ — Performance share unit awards at December 31, 2018 3,966 Granted (4) 8,094 $ 34.00 Performance factor decrease (3) (7,312) $ 34.23 Vested (416) $ 43.00 Forfeited (1,545) $ 37.37 Performance share unit awards at December 31, 2019 2,787 ____________________ (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued. (2) The aggregate grant date fair value of performance share unit awards issued during 2018 was $0.2 million based on a grant date market price of our common shares of $43.00 per share and assuming a performance factor of 100 percent. (3) The performance factor for awards granted in 2018 was lowered to 47.5 percent based on a comparison of actual results for 2018 to performance goals. The performance factor for awards granted in 2019 was lowered to 0 percent based upon a comparison of actual results for 2019 to performance goals. (4) The aggregate grant date fair value of performance share unit awards issued during 2019 was $0.3 million based on a grant date market price of our common shares of $34.00 per share and assuming a performance factor of 100 percent. Unrecognized compensation cost associated with performance share unit awards was approximately $0.1 million at December 31, 2019. We expect to recognize the remaining compensation cost for these awards over a weighted-average period of 1.4 years.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2019
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Supplemental cash flows and non-cash transactions were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Cash paid for interest $ 636 $ 109 $ 22 Cash paid for federal and state income taxes 234 787 459 Non-cash transactions: Change in accounts payable related to property and equipment additions (448) 1,685 70 Property and equipment acquired under finance leases 4,148 2,898 1,808 Issuance of common shares in asset acquisition (see Note 7) 392 — — Receivable for sale of property and equipment 952 — —

Leases

Leases	12 Months Ended
	Dec. 31, 2019
Leases [Abstract]
Leases	Leases Adoption of ASC 842 In February 2016, the Financial Accounting Standards Board issued Accounting Standards Codification 842, Leases (“ASC 842”), which requires lessees to recognize a right-of-use (“ROU”) asset and a corresponding lease liability for leases with terms longer than twelve months. We adopted the new standard effective January 1, 2019, using a modified retrospective transition method and applied certain optional transitional practical expedients. We elected an optional transition method that allowed application of the new standard at the adoption date and the recognition of a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption with no adjustment to previously reported results. In accordance with this approach, our consolidated financial statements for periods prior to January 1, 2019 were not revised to reflect the new lease accounting guidance. We also elected the package of practical expedients permitted under the transition guidance within the new standard, which among other things, allowed the carry forward of historical lease classification. We did not elect the practical expedient related to hindsight. ASC 842 changes the way our operating leases are recorded, presented and disclosed in our consolidated financial statements. Upon adoption of ASC 842 on January 1, 2019, we recognized a ROU asset and a corresponding lease liability based on the present value of then existing operating lease obligations of approximately $11.4 million on our consolidated balance sheet. In addition, there are several key accounting policy elections that we made upon adoption of ASC 842 including: • We did not recognize ROU assets and lease liabilities for short-term leases and instead record them in a manner similar to operating leases under ASC 840, Leases , lease accounting guidelines. A short term lease is one with a maximum lease term of 12 months or less and does not include a purchase option or renewal option the lessee is reasonably certain to exercise. • We have also elected the non-lease component practical expedient for any asset class where lease and non-lease components are comingled and the non-lease component is determined to be insignificant when compared to the lease component. Lease Recognition We determine if an arrangement is a lease at inception. Operating leases are included in operating lease ROU assets, current liabilities and long-term operating lease liabilities in the consolidated balance sheets. Finance leases are included in property and equipment, current liabilities and long-term finance lease liabilities in the consolidated balance sheets. ROU assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. ROU assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term. For determining the present value of lease payments, we use the discount rate implicit in the lease when readily determinable. As most of our leases do not provide an implicit rate, we use an incremental borrowing rate in determining the present value of lease payments that approximates the rate of interest we would have to pay to borrow on a collateralized basis over a similar term. At adoption, the ROU asset also includes any lease payment made and excludes lease incentives and initial direct costs. Our lease terms may include options to extend or terminate the lease when it is reasonably certain that we will exercise that option. Lease expense for lease payments is recognized on a straight-line basis over the lease term. Our lease agreements do not contain any leases with variable lease payments (i.e., payments that depend on a percentage of sales of a lessee or payments that increase based upon an index such as CPI), residual value guarantees probable of being paid or material restrictive covenants. Lease agreements with lease and non-lease components are generally accounted for separately when practical. For leases where the lease and non-lease component are comingled and the non-lease component is determined to be insignificant when compared to the lease component, the lease and the non-lease components are treated as a single lease component for all asset classes. We are a lessee in noncancellable (1) operating leases for office space, equipment and lease and terminal access contracts for tank storage and dock access for our crude oil marketing business, and (2) finance leases for tractors and tank storage and throughput for our crude oil marketing business. Leases with an initial term of twelve months or less are not recorded on the balance sheet. Our lease agreements have remaining lease terms ranging from one year to approximately eight years. Some leases include one or more options to renew, with renewal terms that can extend the lease term for generally one year with exercise of lease renewal options being at our sole discretion as lessee. The following table provides the components of lease expense the period indicated (in thousands): Year Ended December 31, 2019 Finance lease cost: Amortization of ROU assets $ 1,807 Interest on lease liabilities 295 Operating lease cost 2,933 Short-term lease cost 9,627 Total lease expense $ 14,662 The following table provides supplemental cash flow and other information related to leases for the period indicated (in thousands): Year Ended December 31, 2019 Cash paid for amounts included in measurement of lease liabilities: Operating cash flows from operating leases (1) $ 2,934 Operating cash flows from finance leases 295 Financing cash flows from finance leases 1,697 ROU assets obtained in exchange for new lease liabilities: Finance leases 4,148 Operating leases 12,006 ______________ (1) Amount is included in Other operating activities on the consolidated cash flow statement. The following table provides the lease terms and discount rates for the period indicated: Year Ended December 31, 2019 Weighted-average remaining lease term (years): Finance leases 3.03 Operating leases 4.78 Weighted-average discount rate: Finance leases 4.9 % Operating leases 5.0 % The following table provides supplemental balance sheet information related to leases at the date indicated (in thousands): December 31, 2019 Assets Finance lease ROU assets (1) $ 6,384 Operating lease ROU assets 9,576 Liabilities Current Finance lease liabilities 2,167 Operating lease liabilities 2,252 Noncurrent Finance lease liabilities 4,376 Operating lease liabilities 7,323 ______________ (1) Amount is included in Property and equipment, net on the consolidated balance sheet. The following table provides maturities of undiscounted lease liabilities at December 31, 2019 (in thousands): Finance Operating Lease Lease 2020 $ 2,426 $ 2,660 2021 2,426 2,256 2022 1,492 1,914 2023 642 1,776 2024 37 1,668 Thereafter — 443 Total lease payments 7,023 10,717 Less: Interest (480) (1,142) Present value of lease liabilities 6,543 9,575 Less: Current portion of lease obligation (2,167) (2,252) Total long-term lease obligation $ 4,376 $ 7,323 The following table provides maturities of undiscounted lease liabilities at December 31, 2018 (in thousands): Finance Operating Lease Lease 2019 $ 1,052 $ 4,242 2020 1,052 2,258 2021 1,052 2,107 2022 909 1,782 2023 451 1,495 Thereafter — 1,488 Total lease payments 4,516 $ 13,372 Less: Interest (424) Present value of lease liabilities 4,092 Less: Current portion of lease obligation (883) Total long-term lease obligation $ 3,209
Leases	Leases Adoption of ASC 842 In February 2016, the Financial Accounting Standards Board issued Accounting Standards Codification 842, Leases (“ASC 842”), which requires lessees to recognize a right-of-use (“ROU”) asset and a corresponding lease liability for leases with terms longer than twelve months. We adopted the new standard effective January 1, 2019, using a modified retrospective transition method and applied certain optional transitional practical expedients. We elected an optional transition method that allowed application of the new standard at the adoption date and the recognition of a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption with no adjustment to previously reported results. In accordance with this approach, our consolidated financial statements for periods prior to January 1, 2019 were not revised to reflect the new lease accounting guidance. We also elected the package of practical expedients permitted under the transition guidance within the new standard, which among other things, allowed the carry forward of historical lease classification. We did not elect the practical expedient related to hindsight. ASC 842 changes the way our operating leases are recorded, presented and disclosed in our consolidated financial statements. Upon adoption of ASC 842 on January 1, 2019, we recognized a ROU asset and a corresponding lease liability based on the present value of then existing operating lease obligations of approximately $11.4 million on our consolidated balance sheet. In addition, there are several key accounting policy elections that we made upon adoption of ASC 842 including: • We did not recognize ROU assets and lease liabilities for short-term leases and instead record them in a manner similar to operating leases under ASC 840, Leases , lease accounting guidelines. A short term lease is one with a maximum lease term of 12 months or less and does not include a purchase option or renewal option the lessee is reasonably certain to exercise. • We have also elected the non-lease component practical expedient for any asset class where lease and non-lease components are comingled and the non-lease component is determined to be insignificant when compared to the lease component. Lease Recognition We determine if an arrangement is a lease at inception. Operating leases are included in operating lease ROU assets, current liabilities and long-term operating lease liabilities in the consolidated balance sheets. Finance leases are included in property and equipment, current liabilities and long-term finance lease liabilities in the consolidated balance sheets. ROU assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. ROU assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term. For determining the present value of lease payments, we use the discount rate implicit in the lease when readily determinable. As most of our leases do not provide an implicit rate, we use an incremental borrowing rate in determining the present value of lease payments that approximates the rate of interest we would have to pay to borrow on a collateralized basis over a similar term. At adoption, the ROU asset also includes any lease payment made and excludes lease incentives and initial direct costs. Our lease terms may include options to extend or terminate the lease when it is reasonably certain that we will exercise that option. Lease expense for lease payments is recognized on a straight-line basis over the lease term. Our lease agreements do not contain any leases with variable lease payments (i.e., payments that depend on a percentage of sales of a lessee or payments that increase based upon an index such as CPI), residual value guarantees probable of being paid or material restrictive covenants. Lease agreements with lease and non-lease components are generally accounted for separately when practical. For leases where the lease and non-lease component are comingled and the non-lease component is determined to be insignificant when compared to the lease component, the lease and the non-lease components are treated as a single lease component for all asset classes. We are a lessee in noncancellable (1) operating leases for office space, equipment and lease and terminal access contracts for tank storage and dock access for our crude oil marketing business, and (2) finance leases for tractors and tank storage and throughput for our crude oil marketing business. Leases with an initial term of twelve months or less are not recorded on the balance sheet. Our lease agreements have remaining lease terms ranging from one year to approximately eight years. Some leases include one or more options to renew, with renewal terms that can extend the lease term for generally one year with exercise of lease renewal options being at our sole discretion as lessee. The following table provides the components of lease expense the period indicated (in thousands): Year Ended December 31, 2019 Finance lease cost: Amortization of ROU assets $ 1,807 Interest on lease liabilities 295 Operating lease cost 2,933 Short-term lease cost 9,627 Total lease expense $ 14,662 The following table provides supplemental cash flow and other information related to leases for the period indicated (in thousands): Year Ended December 31, 2019 Cash paid for amounts included in measurement of lease liabilities: Operating cash flows from operating leases (1) $ 2,934 Operating cash flows from finance leases 295 Financing cash flows from finance leases 1,697 ROU assets obtained in exchange for new lease liabilities: Finance leases 4,148 Operating leases 12,006 ______________ (1) Amount is included in Other operating activities on the consolidated cash flow statement. The following table provides the lease terms and discount rates for the period indicated: Year Ended December 31, 2019 Weighted-average remaining lease term (years): Finance leases 3.03 Operating leases 4.78 Weighted-average discount rate: Finance leases 4.9 % Operating leases 5.0 % The following table provides supplemental balance sheet information related to leases at the date indicated (in thousands): December 31, 2019 Assets Finance lease ROU assets (1) $ 6,384 Operating lease ROU assets 9,576 Liabilities Current Finance lease liabilities 2,167 Operating lease liabilities 2,252 Noncurrent Finance lease liabilities 4,376 Operating lease liabilities 7,323 ______________ (1) Amount is included in Property and equipment, net on the consolidated balance sheet. The following table provides maturities of undiscounted lease liabilities at December 31, 2019 (in thousands): Finance Operating Lease Lease 2020 $ 2,426 $ 2,660 2021 2,426 2,256 2022 1,492 1,914 2023 642 1,776 2024 37 1,668 Thereafter — 443 Total lease payments 7,023 10,717 Less: Interest (480) (1,142) Present value of lease liabilities 6,543 9,575 Less: Current portion of lease obligation (2,167) (2,252) Total long-term lease obligation $ 4,376 $ 7,323 The following table provides maturities of undiscounted lease liabilities at December 31, 2018 (in thousands): Finance Operating Lease Lease 2019 $ 1,052 $ 4,242 2020 1,052 2,258 2021 1,052 2,107 2022 909 1,782 2023 451 1,495 Thereafter — 1,488 Total lease payments 4,516 $ 13,372 Less: Interest (424) Present value of lease liabilities 4,092 Less: Current portion of lease obligation (883) Total long-term lease obligation $ 3,209

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Insurance Policies We establish a liability under our automobile and workers’ compensation insurance policies for expected claims incurred but not reported on a monthly basis. As claims are paid, the liability is relieved. Our accruals for automobile and workers’ compensation claims are presented in the following table. For periods prior to October 1, 2017, we pre-funded our estimated claims, and therefore, we could 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 was shared with a group of similarly situated entities through an insurance captive. We have appropriately recognized estimated expenses and liabilities related to these policies for losses incurred but not reported to us or our insurance carrier. The amount of pre-funded insurance premiums left to cover potential future losses are presented in the following table. If the potential insurance claims do not further develop, the pre-funded premiums will be returned to us as a premium refund. The amount of pre-funded insurance premiums left to cover potential future losses related to periods prior to October 1, 2017, and our accruals for automobile and workers’ compensation claims were as follows at the dates indicated (in thousands): December 31, 2019 2018 Pre-funded premiums for losses incurred but not reported $ 168 $ 427 Accrued automobile and workers’ compensation claims 2,956 2,246 We maintain a self-insurance program for managing employee medical claims. A liability for expected claims incurred but not reported is established on a monthly basis. As claims are paid, the liability is relieved. We also maintain third party insurance stop-loss coverage for individual medical claims exceeding a certain minimum threshold. In addition, we maintain $1.0 million of umbrella insurance coverage for annual aggregate medical claims exceeding approximately $9.6 million. Medical accrual amounts were as follows at the dates indicated (in thousands): December 31, 2019 2018 Accrued medical claims $ 1,016 $ 1,181 Legal Proceedings On August 15, 2019, we received a notice from the Internal Revenue Service (the “IRS”) regarding a proposed penalty of approximately $1.2 million for our 2017 tax year information returns. The notice alleges that certain taxpayer identification numbers supplied to the IRS for our returns in 2017 were either missing or incorrect and that certain filings were late. We believe that the IRS’ claims are without merit and plan to pursue all available administrative and judicial remedies necessary to resolve this matter. Accordingly, we responded to the IRS on September 25, 2019 disputing the proposed penalty and requesting that the amount be waived, abated or a hearing held. We have not received a response at this time and are unable to predict when this matter might be resolved. We regularly assess the likelihood of adverse outcomes resulting from examinations such as this to determine the adequacy of our tax reserves. Since we are unable to predict whether the IRS will waive or abate the proposed penalty as requested, no liabilities have been accrued to date. We intend to vigorously defend our position in this matter. We believe that the final adjudication of this matter will not have a material impact on our consolidated financial position, results of operations or cash flows. Litigation From time to time as incidental to our operations, we may become involved in various lawsuits and/or disputes. Primarily as an operator of an extensive trucking fleet, we are a party to motor vehicle accidents, worker compensation claims and other items of general liability as would be typical for the industry. We are presently unaware of any claims against us that are either outside the scope of insurance coverage or that may exceed the level of insurance coverage and could potentially represent a material adverse effect on our financial position, results of operations or cash flows. Guarantees AE 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 these arrangements is to guarantee the performance of the subsidiary in meeting their respective underlying obligations. 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 these obligations, the parent would first look to the assets of the defaulting subsidiary company. At December 31, 2019, parental guaranteed obligations were approximately $44.3 million. Currently, neither AE nor any of its subsidiaries has any other types of guarantees outstanding that require liability recognition.

Concentration of Credit Risk

Concentration of Credit Risk	12 Months Ended
	Dec. 31, 2019
Risks and Uncertainties [Abstract]
Concentration of Credit Risk	Concentration of Credit Risk We may incur credit risk to the extent our customers do not fulfill their obligations to us pursuant to contractual terms. Risks of nonpayment and nonperformance by our customers are a major consideration in our business, and our credit procedures and policies may not be adequate to sufficiently eliminate customer credit risk. Managing 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. We have established various procedures to manage credit exposure, including initial credit approval, credit limits and rights of offset. We also utilize letters of credit and guarantees to limit exposure. Our largest customers consist of large multinational integrated crude oil companies and independent domestic refiners of crude oil. In addition, we transact business with independent crude oil producers, major chemical companies, crude oil trading companies and a variety of commercial energy users. Within this group of customers, we derive approximately 50 percent of our revenues from three to five large crude oil refining customers. While we have ongoing established relationships with certain domestic refiners of crude oil, alternative markets are readily available since we supply less than one percent of U.S. domestic refiner demand. As a fungible commodity delivered to major Gulf Coast supply points, our crude oil sales can be readily delivered to alternative end markets. The following tables reflect the percentages of individual customer sales in excess of 10 percent of our consolidated revenues and individual customer receivables in excess of 10 percent of our total consolidated receivables for the periods indicated. We believe that a loss of any of the customers where we currently derive more than 10 percent of our revenues would not have a material adverse effect on our operations. Individual customer sales Individual customer receivables in excess in excess of 10% of revenues of 10% of total receivables Year Ended December 31, December 31, 2019 2018 2017 2019 2018 2017 37.3 % 27.3 % 22.8 % 16.6 % 18.4 % 19.1 % 11.4 % 14.1 % 17.1 % 12.6 % 11.9 % 15.0 % 10.8 % 11.1 % 10.7 % 10.4 %

Quarterly Financial Information

Quarterly Financial Information (Unaudited)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information (Unaudited)	Quarterly Financial Information (Unaudited) The following table presents selected quarterly financial data for the periods indicated (in thousands, except per share data): First Second Third Fourth Quarter Quarter Quarter Quarter Year Ended December 31, 2019 Revenues $ 445,168 $ 484,433 $ 450,307 $ 431,339 Operating (losses) earnings 5,253 (643) 303 2,887 Net (losses) earnings 4,908 6 640 2,653 Earnings (losses) per share: Basic net (losses) earnings per share $ 1.16 $ — $ 0.15 $ 0.63 Diluted net (losses) earnings per share $ 1.16 $ — $ 0.15 $ 0.63 Year Ended December 31, 2018 Revenues $ 387,256 $ 452,417 $ 467,891 $ 442,649 Operating (losses) earnings (1) 1,077 4,298 2,239 (6,206) Net (losses) earnings 1,138 3,620 2,035 (3,848) Earnings (losses) per share: Basic net (losses) earnings per share $ 0.27 $ 0.86 $ 0.48 $ (0.91) Diluted net (losses) earnings per share $ 0.27 $ 0.86 $ 0.48 $ (0.91) ____________________ (1) The fourth quarter of 2018 includes inventory valuation losses of approximately $7.9 million in our crude oil marketing segment.

Oil and Gas Producing Activitie

Oil and Gas Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2019
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Oil and Gas Producing Activities (Unaudited)	Oil and Gas Producing Activities (Unaudited)Our wholly owned subsidiary, AREC, participated in the exploration and development of domestic crude oil and natural gas properties primarily in the Permian Basin of West Texas and the Haynesville Shale. AREC’s offices were maintained in Houston. As discussed further in Note 4, AREC was deconsolidated effective with its bankruptcy filing in April 2017, and we recorded our investment in AREC under the cost method of accounting in April 2017. During the third quarter of 2017, AREC sold substantially all of its assets. As a result of the sales of these assets, we no longer have an ownership interest in any crude oil and natural gas producing activities. In the disclosures and tables below, amounts for 2017 are for the period from January 1, 2017 through April 30, 2017, the period in which AREC was consolidated with us. We had no further exploration and development activity after April 30, 2017. Crude Oil and Natural Gas Producing Activities Total costs incurred in crude oil and natural gas exploration and development activities, all within the U.S., were as follows for the period from January 1, 2017 through April 30, 2017 (in thousands): Property acquisition costs: Unproved $ 4 Exploration costs: Expensed 5 Development costs 1,815 Total costs incurred $ 1,824 Estimated Crude Oil and Natural Gas Reserves The following information regarding estimates of our proved crude oil and natural gas reserves, substantially all of which were located onshore in Texas and Louisiana, was based on reports prepared on our behalf by our independent petroleum engineers. Because crude oil and natural 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. Proved developed and undeveloped reserves were as follows for the period from January 1, 2017 through April 30, 2017 (in thousands): Natural Crude Gas Oil (Mcf) (Bbls) Total proved reserves: Beginning of period 4,214 187 Crude oil and natural gas reserves sold (4,067) (170) Extensions, discoveries and other reserve additions 42 6 Production (189) (23) End of period — — We had developed internal policies and controls for estimating and recording crude oil and natural gas reserve data. The estimation and recording of proved reserves is required to be in compliance with SEC definitions and guidance. We assigned responsibility for compliance in reserve bookings to the office of President of AREC. No portion of this individual’s compensation was 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. We employed a third party petroleum consultant, Ryder Scott Company, to prepare our crude oil and natural gas reserve data estimates as of December 31, 2016. The firm of Ryder Scott has been well recognized within the industry for more than 50 years. As prescribed by the SEC, proved reserves were estimated using 12-month average crude oil and natural gas prices, based on the first-day-of-the-month price for each month in the period, and year-end production and development costs, all without escalation. The process of estimating crude oil and natural 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 crude oil and natural 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, crude oil and natural gas quantities ultimately recovered will vary from reserve estimates. Standardized Measure of Discounted Future Net Cash Flows from Crude Oil and Natural 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 2016, except in those instances where fixed and determinable gas price escalations were included in contracts. The disclosures below do not purport to present the fair market value of our previously owned crude oil and natural 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 was zero for the period from January 1, 2017 through April 30, 2017. The estimated value of crude oil and natural gas reserves and future net revenues derived therefrom are highly dependent upon crude oil and natural gas commodity prices. These 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 included the value of associated natural gas liquids. Crude oil and natural gas reserve values and future net cash flow estimates are very sensitive to pricing assumptions and will vary accordingly. The principal sources of changes in the standardized measure of discounted future net cash flows were as follows for the period from January 1, 2017 through April 30, 2017 (in thousands): Beginning of period $ 2,260 Sale of crude oil and natural gas reserves (2,732) New field discoveries and extensions, net of future production costs 94 Sales of crude oil and natural gas produced, net of production costs (476) Accretion of discount 130 Production rate changes and other (493) Net change in income taxes 1,217 End of period $ — Results of Operations for Crude Oil and Natural Gas Producing Activities The results of crude oil and natural gas producing activities, excluding corporate overhead and interest costs, were as follows for the period from January 1, 2017 through April 30, 2017 (in thousands): Revenues $ 1,427 Costs and expenses: Production (951) Depreciation, depletion and amortization (423) Operating earnings before income taxes 53 Income tax expense (19) Operating earnings $ 34

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Consolidation	Adams Resources & Energy, Inc. (“AE”) is a publicly traded Delaware corporation organized in 1973, the common shares of which are listed on the NYSE American LLC under the ticker symbol “AE”. We, through our subsidiaries, are primarily engaged in the business of crude oil marketing, transportation and storage in various crude oil and natural gas basins in the lower 48 states of the United States (“U.S.”). We also conduct tank truck transportation of liquid chemicals and dry bulk primarily in the lower 48 states of the U.S. with deliveries into Canada and Mexico, and with terminals in the Gulf Coast region of the U.S. Unless the context requires otherwise, references to “we,” “us,” “our,” the “Company” or “AE” are intended to mean the business and operations of Adams Resources & Energy, Inc. and its consolidated subsidiaries. On April 21, 2017, one of our wholly owned subsidiaries, Adams Resources Exploration Corporation (“AREC”), filed a voluntary petition in the United States Bankruptcy Court for the District of Delaware (the “Bankruptcy Court”) seeking relief under Chapter 11 of Title 11 of the United States Code (the “Bankruptcy Code”), Case No. 17-10866 (KG). AREC operated its business and managed its properties as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code and order of the Bankruptcy Court. AE was the primary creditor in the Chapter 11 process. On May 3, 2017, AREC filed a motion with the Bankruptcy Court for approval of an auction process to sell its assets pursuant to Section 363 of the Bankruptcy Code and for approval to engage an advisor to conduct the auction. The auction commenced on July 19, 2017 to determine the highest or otherwise best bid to acquire all or substantially all of AREC’s assets. During the third quarter of 2017, Bankruptcy Court approval was obtained on three asset purchase and sales agreements with three unaffiliated parties, and AREC closed on the sales of substantially all of its assets (see Note 4 for further information). As a result of AREC’s voluntary bankruptcy filing in April 2017, we no longer controlled the operations of AREC; therefore, we deconsolidated AREC effective with the bankruptcy filing and recorded our investment in AREC under the cost method (see Note 4 for further information). We obtained approval of a confirmed plan in December 2017, and the case was dismissed in October 2018. Over the past few years prior to the bankruptcy filing, we have de-emphasized our upstream operations and do not expect this Chapter 11 filing by AREC to have a material adverse impact on any of our core businesses. Historically, we have operated and reported in three business segments: (i) crude oil marketing, transportation and storage, (ii) tank truck transportation of liquid chemicals and dry bulk, and (iii) upstream crude oil and natural gas exploration and production. We exited the crude oil and natural gas exploration and production business during 2017 with the sale of our crude oil and natural gas exploration and production assets (see Note 4 for further information). The consolidated financial statements and the accompanying notes are prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) and the rules of the U.S. Securities and Exchange Commission (“SEC”). All significant intercompany transactions and balances have been eliminated in consolidation.
Use of Estimates	Use of Estimates The preparation of our financial statements in conformity with GAAP requires management to use estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. We base our estimates and judgments on historical experience and on various other assumptions and information we believe to be reasonable under the circumstances. Estimates and assumptions about future events and their effects cannot be perceived with certainty and, accordingly, these estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as the operating environment changes. While we believe the estimates and assumptions used in the preparation of the consolidated financial statements are appropriate, actual results could differ from those estimates.
Accounts Receivable and Allowance for Doubtful Accounts	Accounts Receivable and Allowance for Doubtful Accounts Accounts receivable associated with crude oil marketing activities comprise approximately 90 percent of our total receivables, and industry practice requires payment for these sales to occur within 20 days of the end of the month following a transaction. Our customer makeup, credit policies and the relatively short duration of receivables mitigate the uncertainty typically associated with receivables management. An allowance for doubtful accounts is provided where appropriate. Our allowance for doubtful accounts is determined based on specific identification combined with a review of the general status of the aging of all accounts. We consider the following factors in our review of our allowance for doubtful accounts: (i) historical experience with customers, (ii) the perceived financial stability of customers based on our research, (iii) the levels of credit we grant to customers, and (iv) the duration of the receivable. We may increase the allowance for doubtful accounts in response to the specific identification of customers involved in bankruptcy proceedings and similar financial difficulties. On a routine basis, we review estimates associated with the allowance for doubtful accounts to ensure that we have recorded sufficient reserves to cover potential losses. See Note 18 for further information regarding credit risk.
Cash and Cash Equivalents	Cash and cash equivalents represent unrestricted cash on hand and highly liquid investments with original maturities of less than three months from the date of purchase. Cash and cash equivalents are maintained with major financial institutions, and deposit amounts may exceed the amount of federally backed insurance provided. While we regularly monitor the financial stability of these institutions, cash and cash equivalents ultimately remain at risk subject to the financial viability of these institutions.
Restricted Cash	Restricted cash represented an amount held in a segregated bank account by Wells Fargo as collateral for amounts outstanding under our letter of credit facility prior to its termination.
Derivative Instruments	Derivative Instruments In the normal course of our operations, our crude oil marketing segment purchases and sells crude oil. We seek to profit by procuring the commodity as it is produced and then delivering the product to the end users or the intermediate use marketplace. As typical for the industry, these 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, we account for these contracts at fair value, unless the normal purchase and sale exception is applicable. These types of underlying contracts are standard for the industry and are the governing document for our crude oil marketing segment. None of our derivative instruments have been designated as hedging instruments.
Earnings Per Share	Earnings Per Share Basic earnings (losses) per share is computed by dividing our net earnings (losses) by the weighted average number of shares of common stock outstanding during the period. Diluted earnings (losses) per share is computed by giving effect to all potential shares of common stock outstanding, including our stock related to unvested restricted stock unit awards. Unvested restricted stock unit awards granted under the Adams Resources & Energy, Inc. 2018 Long-Term Incentive Plan (“2018 LTIP”) are not considered to be participating securities as the holders of these shares do not have non-forfeitable dividend rights in the event of our declaration of a dividend for common shares (see Note 14 for further discussion).
Fair Value Measurements	Fair Value Measurements The carrying amounts reported in the consolidated balance sheets 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. Our fair value estimates are based on either (i) actual market data or (ii) assumptions that other market participants would use in pricing an asset or liability, including estimates of risk, in the principal market of the asset or liability at a specified measurement date. Recognized valuation techniques employ inputs such as contractual prices, quoted market prices or rates, operating costs, discount factors and business growth rates. These inputs may be either readily observable, corroborated by market data or generally unobservable. In developing our estimates of fair value, we endeavor to utilize the best information available and apply market-based data to the highest extent possible. Accordingly, we utilize valuation techniques (such as the market approach) that maximize the use of observable inputs and minimize the use of unobservable inputs. A three-tier hierarchy has been established that classifies fair value amounts recognized in the financial statements based on the observability of inputs used to estimate such fair values. The hierarchy considers fair value amounts based on observable inputs (Levels 1 and 2) to be more reliable and predictable than those based primarily on unobservable inputs (Level 3). At each balance sheet reporting date, we categorize our financial assets and liabilities using this hierarchy. The characteristics of the fair value amounts classified within each level of the hierarchy are described as follows: • Level 1 fair values are based on quoted prices, which are available in active markets for identical assets or liabilities as of the measurement date. Active markets are defined as those in which transactions for identical assets or liabilities occur with sufficient frequency so as to provide pricing information on an ongoing basis. For Level 1 valuation of marketable securities, we utilize market quotations provided by our primary financial institution. For the valuations of derivative financial instruments, we utilize the New York Mercantile Exchange (“NYMEX”) for certain commodity valuations. • Level 2 fair values are based on (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 fair values are based on unobservable market data inputs for assets or liabilities. Fair value contracts consist of derivative financial instruments and are recorded as either an asset or liability measured at its fair value. Changes in fair value are recognized immediately in earnings unless the derivatives qualify for, and we elect, cash flow hedge accounting. We had no contracts designated for hedge accounting during any of the current reporting periods (see Note 12 for further information).
Impairment Testing for Long-Lived Assets	Impairment Testing for Long-Lived Assets Long-lived assets (primarily property and equipment and intangible assets) are reviewed for impairment when events or changes in circumstances indicate that the carrying amount of these assets may not be recoverable. Long-lived assets with carrying values that are not expected to be recovered through future cash flows are written-down to their estimated fair values. The carrying value of a long-lived asset is deemed not recoverable if it exceeds the sum of undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the asset’s carrying value exceeds the sum of its undiscounted cash flows, a non-cash asset impairment charge equal to the excess of the asset’s carrying value over its estimated fair value is recorded. Fair value is defined as the price that would be received to sell an asset or be paid to transfer a liability in an orderly transaction between market participants at a specified measurement date. We measure fair value using market price indicators or, in the absence of such data, appropriate valuation techniques. See Note 12 for information regarding impairment charges related to long-lived assets.
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 such items and their respective tax basis (see Note 13 for further information). On December 22, 2017, the Tax Cut and Jobs Act was enacted into law resulting in a reduction in the federal corporate income tax rate from 35 percent to 21 percent for years beginning in 2018, which impacts our income tax provision or benefit.
Inventory	InventoryInventory consists of crude oil held in storage tanks and at third-party pipelines as part of our crude oil marketing operations. Crude oil inventory is carried at the lower of cost or net realizable value. At the end of each reporting period, we assess the carrying value of our inventory and make adjustments necessary to reduce the carrying value to the applicable net realizable value. Any resulting adjustments are a component of marketing costs and expenses on our consolidated statements of operations. During the year ended December 31, 2018, we recorded a charge of $5.4 million related to the write-down of our crude oil inventory due to declines in prices. There were no charges recognized during the years ended December 31, 2019 and 2017.
Letter of Credit Facility	Letter of Credit Facility We maintained a Credit and Security Agreement with Wells Fargo Bank, National Association, to provide for the issuance of up to $60.0 million in stand-by letters of credit primarily used to support crude oil purchases within our crude oil marketing segment and for other purposes. Stand-by letters of credit were issued as needed and were canceled as the underlying purchase obligations were satisfied by cash payment when due. The issuance of stand-by letters of credit enabled us to avoid posting cash collateral when procuring crude oil supply. We used the letter of credit facility for letters of credit related to our insurance program. At December 31, 2018, we had $4.6 million of letters of credit outstanding under this facility.
Property and Equipment	Property and Equipment Property and equipment is recorded at cost. Expenditures for additions, improvements and other enhancements to property and equipment are capitalized, and minor replacements, maintenance and repairs that do not extend asset life or add value are charged to expense as incurred. When property and equipment assets are retired or otherwise disposed of, the related cost and accumulated depreciation is removed from the accounts and any resulting gain or loss is included in results of operations in operating costs and expenses for the respective period. Property and equipment, except for land, is depreciated using the straight-line method over the estimated average useful lives of two thirty-nine Asset retirement obligations (“AROs”) are legal obligations associated with the retirement of tangible long-lived assets that result from their acquisition, construction, development and/or normal operation. When an ARO is incurred, we record a liability for the ARO and capitalize an equal amount as an increase in the carrying value of the related long-lived asset. ARO amounts are measured at their estimated fair value using expected present value techniques. Over time, the ARO liability is accreted to its present value (through accretion expense), and the capitalized amount is depreciated over the remaining useful life of the related long-lived asset. We will incur a gain or loss to the extent that our ARO liabilities are not settled at their recorded amounts.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Measurement of Credit Losses on Financial Instruments . In June 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-13, which replaces the current incurred loss impairment method with a method that reflects expected credit losses on financial instruments. In November 2018, the FASB issued ASU 2018-19, which clarifies the scope of the standard in the amendments in ASU 2016-13. In May 2019, the FASB issued ASU 2019-05, which provides entities with an option to irrevocably elect the fair value option for certain financial instruments. The new standard is effective as of January 1, 2020, and we adopted this standard effective January 1, 2020. We do not believe the adoption of this standard will have a material impact on our consolidated financial statements or on our disclosures.
Share-based Compensation	Stock-Based CompensationWe measure all share-based payment awards, including the issuance of restricted stock unit awards and performance share unit awards to employees and board members, using a fair-value based method. The cost of services received from employees and non-employee board members in exchange for awards of equity instruments is recognized in the consolidated statements of operations based on the estimated fair value of those awards on the grant date and is amortized on a straight-line basis over the requisite service period. The fair value of restricted stock unit awards and performance share unit awards is based on the closing price of our common stock on the grant date. We account for forfeitures as they occur.
Revenue Recognition	Adoption of ASC 606 On January 1, 2018, we adopted ASC 606, Revenue from Contracts with Customers (“ASC 606”) and all related Accounting Standards Updates by applying the modified retrospective method to all contracts that were not completed on January 1, 2018. The modified retrospective approach required us to recognize the cumulative effect of initially applying the new standard as an adjustment to the opening balance of retained earnings on January 1, 2018. Comparative information has not been restated and continues to be reported under the historical accounting standards in effect for those periods. The adoption of the new revenue standard did not result in a cumulative effect adjustment to our retained earnings since there was no significant impact upon adoption of the new standard. There was also no material impact to revenues, or any other financial statement line items for the year ended December 31, 2018 as a result of applying ASC 606. We expect the impact of the adoption of ASC 606 to remain immaterial to our net earnings on an ongoing basis. Revenue Recognition The new revenue standard’s core principle is that a company will recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. The new revenue standard requires entities to recognize revenue through the application of a five-step model, which includes: identification of the contract; identification of the performance obligations; determination of the transaction price; allocation of the transaction price to the performance obligations; and recognition of revenue as the entity satisfies the performance obligations. Our revenues are primarily generated from the marketing, transportation and storage of crude oil and other related products and the tank truck transportation of liquid chemicals and dry bulk. A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account in ASC 606. To identify the performance obligations, we considered all of the products or services promised in the contracts with customers, whether explicitly stated or implied based on customary business practices. Revenue is recognized when, or as, each performance obligation is satisfied under terms of the contract. Payment is typically due in full within 30 days of the invoice date. For our crude oil marketing segment, most of our crude oil purchase and sale contracts qualify and are designated as non-trading activities, and we consider these contracts as normal purchases and sales activity. For normal purchases and sales, our 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, generally upon delivery of the product to the customer. Revenue is recognized based on the transaction price and the quantity delivered. The majority of our crude oil sales contracts have multiple distinct performance obligations as the promise to transfer the individual goods (e.g., barrels of crude oil) is separately identifiable from the other goods promised within the contracts. Our performance obligations are satisfied at a point in time. For normal sales arrangements, revenue is recognized in the month in which control of the physical product is transferred to the customer, generally upon delivery of the product to the customer. For our transportation segment, each sales order associated with our master transportation agreements is considered a distinct performance obligation. The performance obligations associated with this segment are satisfied over time as the goods and services are delivered. Practical Expedients In connection with our adoption of ASC 606, we reviewed our revenue contracts for impact upon adoption. For example, our revenue contracts often include promises to transfer various goods and services to a customer. Determining whether goods and services are considered distinct performance obligations that should be accounted for separately versus together will continue to require continual assessment. We also used practical expedients permitted by ASC 606 when applicable. These practical expedients included: • Applying the new guidance only to contracts that were not completed as of January 1, 2018; and • Not accounting for the effects of significant financing components if the company expects that the period between when the entity transfers a promised good or service to a customer and when the customer pays for that good or service will be one year or less. Contract Balances Other Crude Oil Marketing Revenue Certain of the commodity purchase and sale contracts utilized by our crude oil marketing segment qualify as derivative instruments with certain specifically identified contracts also designated as trading activity. From the time of contract origination, these contracts are marked-to-market and recorded on a net revenue basis in the accompanying consolidated financial statements.
Asset Retirement Obligations	We record AROs for the estimated retirement costs associated with certain tangible long-lived assets. The estimated fair value of AROs are recorded in the period in which they are incurred and the corresponding cost is 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. If the liability is settled for an amount other than the recorded amount, an increase or decrease to expense is recognized.
Cash Deposits and Other Assets	We have established certain deposits to support participation in our liability insurance program and remittance of state crude oil severance taxes and other state collateral deposits. Insurance collateral deposits are held by the insurance company to cover past or potential open claims based upon a percentage of the maximum assessment under our insurance policies. Insurance collateral deposits are invested at the discretion of our insurance carrier. Excess amounts in our loss fund represent premium payments in excess of claims incurred to date that we may be entitled to recover through settlement or commutation as claim periods are closed. Interest income is earned on the majority of amounts held by the insurance companies and will be paid to us upon settlement of policy years.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Changes in the Allowance for Doubtful Accounts	The following table presents our allowance for doubtful accounts activity for the periods indicated (in thousands): December 31, 2019 2018 2017 Balance at beginning of period $ 153 $ 303 $ 225 Charges to costs and expenses 26 43 137 Deductions (38) (193) (59) Balance at end of period $ 141 $ 153 $ 303
Summary of Cash and Cash Equivalents and Restricted Cash	The following table provides a reconciliation of cash and cash equivalents and restricted cash as reported in the consolidated balance sheets that totals to the amounts shown in the consolidated statements of cash flows (in thousands): December 31, 2019 2018 Cash and cash equivalents $ 112,994 $ 117,066 Restricted cash 9,261 — Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 122,255 $ 117,066
Schedule of Common Stock	The following table reconciles our outstanding common stock for the periods indicated: Common shares Balance, December 31, 2017 and 2018 4,217,596 Issuance of shares in acquisition (see Note 7) 11,145 Vesting of restricted stock unit awards (see Note 14) 7,604 Shares withheld to cover taxes upon vesting of restricted stock unit awards (883) Other 71 Balance, December 31, 2019 4,235,533
Schedule of Earnings per Share, Basic and Diluted	A reconciliation of the calculation of basic and diluted earnings (losses) per share was as follows for the periods indicated (in thousands, except per share data): Year Ended December 31, 2019 2018 2017 Earnings (losses) per share – numerator: Net (losses) earnings $ 8,207 $ 2,945 $ (482) Denominator: Basic weighted average number of shares outstanding 4,228 4,218 4,218 Basic earnings (losses) per share $ 1.94 $ 0.70 $ (0.11) Diluted earnings (losses) per share: Diluted weighted average number of shares outstanding: Common shares 4,228 4,218 4,218 Restricted stock unit awards (1) 5 — — Performance share unit awards (2) — — — Total 4,233 4,218 4,218 Diluted earnings (losses) per share $ 1.94 $ 0.70 $ (0.11) _______________ (1) The dilutive effect of restricted stock unit awards for the year ended December 31, 2018 is de minimis.
Schedule of Cost of Retirement Plans	Our 401(k) plan contributory expenses were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Contributory expenses $ 1,117 $ 808 $ 734

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table disaggregates our revenue by segment and by major source for the periods indicated (in thousands): Reporting Segments Marketing Transportation Total Year Ended December 31, 2019 Revenues from contracts with customers $ 1,555,393 $ 63,191 $ 1,618,584 Other (1) 192,663 — 192,663 Total revenues $ 1,748,056 $ 63,191 $ 1,811,247 Timing of revenue recognition: Goods transferred at a point in time $ 1,555,393 $ — $ 1,555,393 Services transferred over time — 63,191 63,191 Total revenues from contracts with customers $ 1,555,393 $ 63,191 $ 1,618,584 Year Ended December 31, 2018 Revenues from contracts with customers $ 1,580,997 $ 55,776 $ 1,636,773 Other (1) 113,440 — 113,440 Total revenues $ 1,694,437 $ 55,776 $ 1,750,213 Timing of revenue recognition: Goods transferred at a point in time $ 1,580,997 $ — $ 1,580,997 Services transferred over time — 55,776 55,776 Total revenues from contracts with customers $ 1,580,997 $ 55,776 $ 1,636,773 _______________ (1) Other crude oil marketing revenues are recognized under ASC 815, Derivatives and Hedging , and ASC 845, Nonmonetary Transactions – Purchases and Sales of Inventory with the Same Counterparty
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	Reporting these crude oil contracts on a gross revenue basis would increase our reported revenues as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Revenue gross-up $ 859,091 $ 448,846 $ 203,095

Prepayments and Other Current_2

Prepayments and Other Current Assets (Tables)	12 Months Ended
	Dec. 31, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepayments and Other Current Assets	The components of prepayments and other current assets were as follows at the dates indicated (in thousands): December 31, 2019 2018 Insurance premiums $ 473 $ 677 Rents, licenses and other 1,086 880 Total $ 1,559 $ 1,557

Property and Equipment (Tables)

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Property and equipment	The historical costs of our property and equipment and related accumulated depreciation balances were as follows at the dates indicated (in thousands): Estimated Useful Life December 31, in Years 2019 2018 Tractors and trailers (1) 5 – 6 $ 115,693 $ 96,523 Field equipment (2) 2 – 5 25,094 20,725 Buildings 5 – 39 16,055 15,746 Office equipment 2 – 5 1,951 1,863 Land 1,790 1,790 Construction in progress 3,661 2,794 Total 164,244 139,441 Less accumulated depreciation (95,198) (94,818) Property and equipment, net $ 69,046 $ 44,623 ______________ (1) Amounts include tractors held under finance leases in our crude oil marketing segment. At December 31, 2019 and 2018, gross property and equipment associated with these assets held under finance leases were $5.5 million and $4.7 million, respectively. Accumulated amortization associated with these assets held under finance leases were $1.7 million and $0.7 million at December 31, 2019 and 2018, respectively (see Note 16 for further information). (2) 2019 amount includes a tank storage and throughput arrangement in our crude oil marketing segment held under a finance lease. Gross property and equipment associated with these assets held under a finance lease at December 31, 2019 was $3.3 million. Accumulated amortization associated with these assets held under a finance lease at December 31, 2019 was $0.7 million (see Note 16 for further information). Components of depreciation, depletion and amortization expense were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Depreciation, depletion and amortization, excluding amounts under finance leases $ 14,833 $ 10,112 $ 13,478 Amortization of property and equipment under finance leases 1,808 542 121 Total depreciation, depletion and amortization $ 16,641 $ 10,654 $ 13,599
Pre-tax gain on the sale of equipment	We sold certain used tractors, trailers and other equipment and recorded net pre-tax gains as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Gains on sales of used tractors, trailers and equipment $ 1,400 $ 1,240 $ 594
Company's asset retirement obligations	The following table reflects a summary of our AROs for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 ARO liability at beginning of year $ 1,525 $ 1,273 $ 2,329 Liabilities incurred 17 252 18 Accretion of discount 48 36 58 Liabilities settled (17) (36) (261) Deconsolidation of subsidiary (1) — — (871) ARO liability at end of year $ 1,573 $ 1,525 $ 1,273 _______________

Asset Acquisition (Tables)

Asset Acquisition (Tables)	12 Months Ended
	Dec. 31, 2019
Asset Acquisition [Abstract]
Schedule of Asset Acquisition	The following table summarizes the consideration paid for the EH Transport assets and the estimated fair value of the assets acquired at the acquisition date (in thousands): Consideration: Cash $ 5,624 Value of AE common shares issued 392 Contingent consideration arrangement 431 Fair value of total consideration transferred $ 6,447 Recognized amounts of identifiable assets acquired: Property and equipment — tractors and trailers $ 4,576 Shop, office and telecommunication equipment 20 Intangible assets — customer relationships 1,851 Total purchase price $ 6,447 Tractors $ 4,799 Trailers 4,901 Field equipment 381 Materials and supplies 191 Total purchase price $ 10,272
Schedule of Future Amortization Expense	The following table presents our forecast of amortization expense associated with these intangible assets for the years indicated (in thousands): 2020 2021 2022 2023 2024 Amortization expense $ 302 $ 283 $ 263 $ 244 $ 227

Cash Deposits and Other Assets

Cash Deposits and Other Assets (Tables)	12 Months Ended
	Dec. 31, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Components of cash deposits and other assets	Components of cash deposits and other assets were as follows at the dates indicated (in thousands): December 31, 2019 2018 Amounts associated with liability insurance program: Insurance collateral deposits $ 1,233 $ 1,453 Excess loss fund 943 1,916 Accumulated interest income 609 788 Other amounts: State collateral deposits 37 57 Materials and supplies 477 443 Total $ 3,299 $ 4,657

Segment Reporting (Tables)

Segment Reporting (Tables)	12 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Information Concerning Business Activities	Financial information by reporting segment was as follows for the periods indicated (in thousands): Reporting Segments Marketing Transportation Oil and Gas and Other (1) Total Year Ended December 31, 2019 Revenues $ 1,748,056 $ 63,191 $ — $ 1,811,247 Segment operating (losses) earnings (2) 16,099 1,899 — 17,998 Depreciation, depletion and amortization 8,741 7,900 — 16,641 Property and equipment additions (4) 7,249 28,472 22 35,743 Year Ended December 31, 2018 Revenues $ 1,694,437 $ 55,776 $ — $ 1,750,213 Segment operating (losses) earnings (2) 7,008 3,337 — 10,345 Depreciation, depletion and amortization 6,384 4,270 — 10,654 Property and equipment additions (4) (5) 1,540 10,178 13 11,731 Year Ended December 31, 2017 Revenues $ 1,267,275 $ 53,358 $ 1,427 $ 1,322,060 Segment operating (losses) earnings (2) (3) 11,700 (544) 53 11,209 Depreciation, depletion and amortization 7,812 5,364 423 13,599 Property and equipment additions 468 351 1,825 2,644 _________________ (1) Amounts presented for the year ended December 31, 2017 are related to our upstream crude oil and natural gas exploration and production segment prior to its deconsolidation. (2) Our crude oil marketing segment’s operating earnings included inventory liquidation gains of $3.7 million and $3.3 million, respectively, for the years ended December 31, 2019 and 2017, and inventory valuation losses of $5.4 million for the year ended December 31, 2018. (3) Segment operating (losses) earnings for the year ended December 31, 2017 includes approximately $0.4 million of costs related to a voluntary early retirement program that was implemented in August 2017. (4) Our crude oil marketing segment’s property and equipment additions do not include approximately $4.1 million, $2.9 million and $1.8 million of assets acquired under finance leases during the years ended December 31, 2019, 2018 and 2017, respectively. See Note 16 for further information.
Reconciliation of Segment Earnings to Earnings Before Income Taxes	Segment operating earnings reflect revenues net of operating costs and depreciation, depletion and amortization expense and are reconciled to earnings (losses) before income taxes, as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Segment operating earnings $ 17,998 $ 10,345 $ 11,209 General and administrative (1) (10,198) (8,937) (9,707) Operating earnings 7,800 1,408 1,502 Loss on deconsolidation of subsidiary — — (3,505) Impairment of investment in unconsolidated affiliate — — (2,500) Gain on dissolution of investment 573 — — Interest income 2,766 2,155 1,103 Interest expense (636) (109) (27) (Losses) earnings before income taxes $ 10,503 $ 3,454 $ (3,427) _______________
Identifiable Assets by Industry Segment	Identifiable assets by industry segment were as follows at the dates indicated (in thousands): December 31, 2019 2018 2017 Reporting segment: Marketing $ 141,402 $ 119,370 $ 134,745 Transportation 58,483 34,112 29,069 Oil and Gas (1) — — 425 Cash and other 130,957 125,388 118,465 Total assets $ 330,842 $ 278,870 $ 282,704 ____________________ (1) At December 31, 2017, amount represents our remaining cost method investment in this segment. See Note 4 for further information.

Transactions with Affiliates (T

Transactions with Affiliates (Tables)	12 Months Ended
	Dec. 31, 2019
Related Party Transactions [Abstract]
Schedule of activities with affiliates	Activities with affiliates were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Affiliate billings to us $ 83 $ 75 $ 81 Billings to affiliates 5 6 4 Rentals paid to affiliate 487 487 583 Fee paid to Bencap (1) — — 108 ___________________ (1) Amount represents fees paid to Bencap through the forfeiture of our investment during the first quarter of 2017. As a result of the investment forfeiture, Bencap is no longer an affiliate.

Derivative Instruments and Fa_2

Derivative Instruments and Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives Reflected in the Consolidated Balance Sheet	The estimated fair value of forward month commodity contracts (derivatives) reflected in the accompanying consolidated balance sheets were as follows at the dates indicated (in thousands): Balance Sheet Location and Amount Current Other Current Other December 31, 2019 Assets Assets Liabilities Liabilities Asset derivatives: Fair value forward hydrocarbon commodity contracts at gross valuation $ — $ — $ — $ — Liability derivatives: Fair value forward hydrocarbon commodity contracts at gross valuation — — — — Less counterparty offsets — — — — As reported fair value contracts $ — $ — $ — $ — December 31, 2018 Asset derivatives: Fair value forward hydrocarbon commodity contracts at gross valuation $ 162 $ — $ — $ — Liability derivatives: Fair value forward hydrocarbon commodity contracts at gross valuation — — 139 — Less counterparty offsets — — — — As reported fair value contracts $ 162 $ — $ 139 $ —
Derivatives Reflected in the Consolidated Statement of Operations	Forward month commodity contracts (derivatives) reflected in the accompanying consolidated statements of operations were as follows for the periods indicated (in thousands): Gains (Losses) Year Ended December 31, 2019 2018 2017 Revenues – marketing $ (24) $ 2 $ (26)
Fair Value Assets and Liabilities	The following table reflects, by level with the Level 1, 2 and 3 fair value hierarchy, the carrying values of our financial assets and liabilities at the dates indicated (in thousands): Fair Value Measurements Using Quoted Prices in Active Significant Markets for Other Significant Identical Assets Observable Unobservable and Liabilities Inputs Inputs Counterparty (Level 1) (Level 2) (Level 3) Offsets Total December 31, 2019 Derivatives: Current assets $ — $ — $ — $ — $ — Current liabilities — — — — — Net value $ — $ — $ — $ — $ — December 31, 2018 Derivatives: Current assets $ — $ 162 $ — $ — $ 162 Current liabilities — (139) — — (139) Net value $ — $ 23 $ — $ — $ 23
Fair Value, Nonrecurring	Certain nonfinancial assets and liabilities are measured at fair value on a nonrecurring basis and are subject to fair value adjustments in certain circumstances, such as when there is evidence of impairment. During the years ended December 31, 2019 and 2018, we had no long-lived assets that were subject to non-recurring fair value measurements. The following table presents categories of long-lived assets that were subject to non-recurring fair value measurements during the year ended December 31, 2017 (in thousands): Fair Value Measurements at the End of the Reporting Period Using Quoted Prices in Active Significant Carrying Markets for Other Significant Total Value at Identical Assets Observable Unobservable Non-Cash December 31, and Liabilities Inputs Inputs Impairment 2017 (Level 1) (Level 2) (Level 3) Loss Oil and gas properties — Investment in AREC $ 425 $ — $ 425 $ — $ 3,505 Investment in VestaCare — — — — 2,500 $ 6,005

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Components of the Company's Income Tax (Provision) Benefit	The components of our income tax (provision) benefit were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Current: Federal $ 164 $ 388 $ (1,418) State (375) 39 523 Total current (211) 427 (895) Deferred: Federal (2,063) (752) 3,722 State (22) (184) 118 Total deferred (2,085) (936) 3,840 Total (provision for) benefit from income taxes $ (2,296) $ (509) $ 2,945
Reconciliation of Taxes Computed at the Corporate Federal Income Tax Rate to the Reported Income Tax (Provision)	A reconciliation of the (provision for) benefit from income taxes with amounts determined by applying the statutory U.S. federal income tax rate to income before income taxes was as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Pre-tax net book income (loss) $ 10,503 $ 3,454 $ (3,427) Statutory federal income tax (provision) benefit $ (2,206) $ (725) $ 1,165 State income tax (provision) benefit (397) (145) 736 Federal statutory depletion — — 153 Federal tax rate adjustment — — 2,007 Valuation allowance — — (1,038) Reverse valuation allowance — 98 — Return to provision adjustments 285 388 — Other 22 (125) (78) Total (provision for) benefit from income taxes $ (2,296) $ (509) $ 2,945 Effective income tax rate (1) (2) 22 % 15 % 86 % _______________ (1) Excluding the adjustment related to the federal tax rate change, the effective income tax rate for 2018 is 26 percent.
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 these items. The components of the federal deferred tax asset (liability) were as follows at the dates indicated (in thousands): December 31, 2019 2018 Long-term deferred tax asset (liability): Prepaid and other insurance $ 248 $ (170) Property (9,953) (5,259) Investments in unconsolidated affiliates 525 525 Valuation allowance related to investments in unconsolidated affiliates (525) (525) Net operating loss 3,567 1,436 Other (184) (245) Net long-term deferred tax liability (6,322) (4,238) Net deferred tax liability $ (6,322) $ (4,238)
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 2015 Texas 2015 Louisiana 2016 Michigan 2015

Share-Based Compensation Plan (

Share-Based Compensation Plan (Tables)	12 Months Ended
	Dec. 31, 2019
Share-based Payment Arrangement [Abstract]
Schedule of Share-based Payment Arrangement	Compensation expense recognized in connection with equity-based awards was as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Compensation expense $ 478 $ 255 $ —
Share-based Compensation, Activity	The following table presents restricted stock unit award activity for the periods indicated: Weighted- Average Grant Number of Date Fair Value Shares per Share (1) Restricted stock unit awards at January 1, 2018 — $ — Granted (2) 13,733 $ 43.00 Vested — $ — Forfeited — $ — Restricted stock unit awards at December 31, 2018 13,733 Granted (3) 14,376 $ 34.00 Vested (7,188) $ 41.90 Forfeited (2,139) $ 38.42 Restricted stock unit awards at December 31, 2019 18,782 ____________________ (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued. (2) The aggregate grant date fair value of restricted stock unit awards issued during 2018 was $0.6 million based on a grant date market price of our common shares of $43.00 per share. (3) The aggregate grant date fair value of restricted stock unit awards issued during 2019 was $0.5 million based on a grant date market price of our common shares of $34.00 per share. The following table presents performance share unit award activity for the periods indicated: Weighted- Average Grant Number of Date Fair Value Shares per Share (1) Performance share unit awards at January 1, 2018 — $ — Granted (2) 7,932 $ 43.00 Performance factor decrease (3) (3,966) $ 43.00 Vested — $ — Forfeited — $ — Performance share unit awards at December 31, 2018 3,966 Granted (4) 8,094 $ 34.00 Performance factor decrease (3) (7,312) $ 34.23 Vested (416) $ 43.00 Forfeited (1,545) $ 37.37 Performance share unit awards at December 31, 2019 2,787 ____________________ (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued. (2) The aggregate grant date fair value of performance share unit awards issued during 2018 was $0.2 million based on a grant date market price of our common shares of $43.00 per share and assuming a performance factor of 100 percent. (3) The performance factor for awards granted in 2018 was lowered to 47.5 percent based on a comparison of actual results for 2018 to performance goals. The performance factor for awards granted in 2019 was lowered to 0 percent based upon a comparison of actual results for 2019 to performance goals.

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2019
Supplemental Cash Flow Elements [Abstract]
Schedule of supplemental cash flow information	Supplemental cash flows and non-cash transactions were as follows for the periods indicated (in thousands): Year Ended December 31, 2019 2018 2017 Cash paid for interest $ 636 $ 109 $ 22 Cash paid for federal and state income taxes 234 787 459 Non-cash transactions: Change in accounts payable related to property and equipment additions (448) 1,685 70 Property and equipment acquired under finance leases 4,148 2,898 1,808 Issuance of common shares in asset acquisition (see Note 7) 392 — — Receivable for sale of property and equipment 952 — —

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2019
Leases [Abstract]
Schedule of Lease Cost	The following table provides the components of lease expense the period indicated (in thousands): Year Ended December 31, 2019 Finance lease cost: Amortization of ROU assets $ 1,807 Interest on lease liabilities 295 Operating lease cost 2,933 Short-term lease cost 9,627 Total lease expense $ 14,662 The following table provides supplemental cash flow and other information related to leases for the period indicated (in thousands): Year Ended December 31, 2019 Cash paid for amounts included in measurement of lease liabilities: Operating cash flows from operating leases (1) $ 2,934 Operating cash flows from finance leases 295 Financing cash flows from finance leases 1,697 ROU assets obtained in exchange for new lease liabilities: Finance leases 4,148 Operating leases 12,006 ______________ (1) Amount is included in Other operating activities on the consolidated cash flow statement. The following table provides the lease terms and discount rates for the period indicated: Year Ended December 31, 2019 Weighted-average remaining lease term (years): Finance leases 3.03 Operating leases 4.78 Weighted-average discount rate: Finance leases 4.9 % Operating leases 5.0 %
Schedule of Lease Assets and Liabilities	The following table provides supplemental balance sheet information related to leases at the date indicated (in thousands): December 31, 2019 Assets Finance lease ROU assets (1) $ 6,384 Operating lease ROU assets 9,576 Liabilities Current Finance lease liabilities 2,167 Operating lease liabilities 2,252 Noncurrent Finance lease liabilities 4,376 Operating lease liabilities 7,323 ______________ (1) Amount is included in Property and equipment, net on the consolidated balance sheet.
Schedule of Lessee, Operating Lease, Liability, Maturity	The following table provides maturities of undiscounted lease liabilities at December 31, 2019 (in thousands): Finance Operating Lease Lease 2020 $ 2,426 $ 2,660 2021 2,426 2,256 2022 1,492 1,914 2023 642 1,776 2024 37 1,668 Thereafter — 443 Total lease payments 7,023 10,717 Less: Interest (480) (1,142) Present value of lease liabilities 6,543 9,575 Less: Current portion of lease obligation (2,167) (2,252) Total long-term lease obligation $ 4,376 $ 7,323
Schedule of Finance Lease, Liability, Maturity	The following table provides maturities of undiscounted lease liabilities at December 31, 2019 (in thousands): Finance Operating Lease Lease 2020 $ 2,426 $ 2,660 2021 2,426 2,256 2022 1,492 1,914 2023 642 1,776 2024 37 1,668 Thereafter — 443 Total lease payments 7,023 10,717 Less: Interest (480) (1,142) Present value of lease liabilities 6,543 9,575 Less: Current portion of lease obligation (2,167) (2,252) Total long-term lease obligation $ 4,376 $ 7,323
Schedule of Principal Contractual Commitments Outstanding Under our Capital Leases	The following table provides maturities of undiscounted lease liabilities at December 31, 2018 (in thousands): Finance Operating Lease Lease 2019 $ 1,052 $ 4,242 2020 1,052 2,258 2021 1,052 2,107 2022 909 1,782 2023 451 1,495 Thereafter — 1,488 Total lease payments 4,516 $ 13,372 Less: Interest (424) Present value of lease liabilities 4,092 Less: Current portion of lease obligation (883) Total long-term lease obligation $ 3,209
Schedule of Principal Contractual Commitments Outstanding Under our Operating Leases	The following table provides maturities of undiscounted lease liabilities at December 31, 2018 (in thousands): Finance Operating Lease Lease 2019 $ 1,052 $ 4,242 2020 1,052 2,258 2021 1,052 2,107 2022 909 1,782 2023 451 1,495 Thereafter — 1,488 Total lease payments 4,516 $ 13,372 Less: Interest (424) Present value of lease liabilities 4,092 Less: Current portion of lease obligation (883) Total long-term lease obligation $ 3,209

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Schedule of Expenses and Losses Incurred but Not Reported	The amount of pre-funded insurance premiums left to cover potential future losses related to periods prior to October 1, 2017, and our accruals for automobile and workers’ compensation claims were as follows at the dates indicated (in thousands): December 31, 2019 2018 Pre-funded premiums for losses incurred but not reported $ 168 $ 427 Accrued automobile and workers’ compensation claims 2,956 2,246
Schedule of Accrued Medical Claims	Medical accrual amounts were as follows at the dates indicated (in thousands): December 31, 2019 2018 Accrued medical claims $ 1,016 $ 1,181

Concentration of Credit Risk (T

Concentration of Credit Risk (Tables)	12 Months Ended
	Dec. 31, 2019
Risks and Uncertainties [Abstract]
Schedule of Concentration of Risk	We believe that a loss of any of the customers where we currently derive more than 10 percent of our revenues would not have a material adverse effect on our operations. Individual customer sales Individual customer receivables in excess in excess of 10% of revenues of 10% of total receivables Year Ended December 31, December 31, 2019 2018 2017 2019 2018 2017 37.3 % 27.3 % 22.8 % 16.6 % 18.4 % 19.1 % 11.4 % 14.1 % 17.1 % 12.6 % 11.9 % 15.0 % 10.8 % 11.1 % 10.7 % 10.4 %

Quarterly Financial Informati_2

Quarterly Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Selected Quarterly Financial Data and Earnings Per Share	The following table presents selected quarterly financial data for the periods indicated (in thousands, except per share data): First Second Third Fourth Quarter Quarter Quarter Quarter Year Ended December 31, 2019 Revenues $ 445,168 $ 484,433 $ 450,307 $ 431,339 Operating (losses) earnings 5,253 (643) 303 2,887 Net (losses) earnings 4,908 6 640 2,653 Earnings (losses) per share: Basic net (losses) earnings per share $ 1.16 $ — $ 0.15 $ 0.63 Diluted net (losses) earnings per share $ 1.16 $ — $ 0.15 $ 0.63 Year Ended December 31, 2018 Revenues $ 387,256 $ 452,417 $ 467,891 $ 442,649 Operating (losses) earnings (1) 1,077 4,298 2,239 (6,206) Net (losses) earnings 1,138 3,620 2,035 (3,848) Earnings (losses) per share: Basic net (losses) earnings per share $ 0.27 $ 0.86 $ 0.48 $ (0.91) Diluted net (losses) earnings per share $ 0.27 $ 0.86 $ 0.48 $ (0.91) ____________________ (1) The fourth quarter of 2018 includes inventory valuation losses of approximately $7.9 million in our crude oil marketing segment.

Oil and Gas Producing Activit_2

Oil and Gas Producing Activities (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Cost Incurred in Oil and Gas Exploration and Development Activities	Total costs incurred in crude oil and natural gas exploration and development activities, all within the U.S., were as follows for the period from January 1, 2017 through April 30, 2017 (in thousands): Property acquisition costs: Unproved $ 4 Exploration costs: Expensed 5 Development costs 1,815 Total costs incurred $ 1,824
Proved Developed and Undeveloped Oil and Gas Reserves	Proved developed and undeveloped reserves were as follows for the period from January 1, 2017 through April 30, 2017 (in thousands): Natural Crude Gas Oil (Mcf) (Bbls) Total proved reserves: Beginning of period 4,214 187 Crude oil and natural gas reserves sold (4,067) (170) Extensions, discoveries and other reserve additions 42 6 Production (189) (23) End of period — —
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 cash flows were as follows for the period from January 1, 2017 through April 30, 2017 (in thousands): Beginning of period $ 2,260 Sale of crude oil and natural gas reserves (2,732) New field discoveries and extensions, net of future production costs 94 Sales of crude oil and natural gas produced, net of production costs (476) Accretion of discount 130 Production rate changes and other (493) Net change in income taxes 1,217 End of period $ —
Results of Operations for Oil and Gas Producing Activities	The results of crude oil and natural gas producing activities, excluding corporate overhead and interest costs, were as follows for the period from January 1, 2017 through April 30, 2017 (in thousands): Revenues $ 1,427 Costs and expenses: Production (951) Depreciation, depletion and amortization (423) Operating earnings before income taxes 53 Income tax expense (19) Operating earnings $ 34

Organization and Basis of Pre_2

Organization and Basis of Presentation (Details)	3 Months Ended	12 Months Ended
	Sep. 30, 2017agreement	Dec. 31, 2019segmentstate	Dec. 31, 2018segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of states in which entity operates | state		48
Number of asset purchase and sales agreements with three unaffiliated parties | agreement	3
Number of operating segments			3
Number of reportable segments		3

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Accounts Receivable and Allowance for Doubtful Accounts (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Industry practice payment of receivables	20 days
Changes in the allowance for doubtful accounts [Roll Forward]
Balance at beginning of period	$ 153	$ 303	$ 225
Charges to costs and expenses	26	43	137
Deductions	(38)	(193)	(59)
Balance at end of period	$ 141	$ 153	$ 303
Product Concentration Risk | Accounts Receivable
Concentration Risk [Line Items]
Concentration risk, percentage	90.00%

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Reconciliation of Cash and Restricted Cash (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
Cash and cash equivalents	$ 112,994	$ 117,066
Restricted cash	9,261	0
Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows	$ 122,255	$ 117,066	$ 109,393	$ 87,342

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Common Shares Outstanding (Details)	12 Months Ended
	Dec. 31, 2019shares
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	4,217,596
Issuance of shares in acquisition (in shares)	11,145
Vesting of restricted stock unit awards (in shares)	7,604
Shares withheld to cover taxes upon vesting of restricted stock unit awards (in shares)	(883)
Other (in shares)	71
Ending balance (in shares)	4,235,533

Summary of Significant Accoun_7

Summary of Significant Accounting Policies - Earnings per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Net (losses) earnings	$ 2,653	$ 640	$ 6	$ 4,908	$ (3,848)	$ 2,035	$ 3,620	$ 1,138	$ 8,207	$ 2,945	$ (482)
Basic weighted average number of shares outstanding (in shares)									4,228	4,218	4,218
Basic earnings (losses) per share (in dollars per share)	$ 0.63	$ 0.15	$ 0	$ 1.16	$ (0.91)	$ 0.48	$ 0.86	$ 0.27	$ 1.94	$ 0.70	$ (0.11)
Diluted weighted average number of shares outstanding (in shares)									4,233	4,218	4,218
Diluted earnings (losses) per share (in dollars per share)	$ 0.63	$ 0.15	$ 0	$ 1.16	$ (0.91)	$ 0.48	$ 0.86	$ 0.27	$ 1.94	$ 0.70	$ (0.11)
Restricted stock units awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units award (in shares)									5	0	0
Performance share unit awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units award (in shares)									0	0	0

Summary of Significant Accoun_8

Summary of Significant Accounting Policies - Employee Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Contributory expenses	$ 1,117	$ 808	$ 734

Summary of Significant Accoun_9

Summary of Significant Accounting Policies - Inventory (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Inventory write-down	$ 0	$ 5,400,000	$ 0

Summary of Significant Accou_10

Summary of Significant Accounting Policies - Letter of Credit Facility (Details) - Wells Fargo Bank - USD ($)	Dec. 31, 2019	Dec. 31, 2018
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity	$ 60,000,000
Standby Letters of Credit
Line of Credit Facility [Line Items]
Letters of credit outstanding		$ 4,600,000

Summary of Significant Accou_11

Summary of Significant Accounting Policies - Property and Equipment (Details)	12 Months Ended
	Dec. 31, 2019
Minimum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	2 years
Maximum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	39 years

Revenue Recognition - Revenue D

Revenue Recognition - Revenue Disaggregation (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenue from Contract with Customer [Abstract]
Revenue, performance obligation, description of timing									Payment is typically due in full within 30 days of the invoice date.
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									$ 1,618,584	$ 1,636,773
Other									192,663	113,440
Total revenues	$ 431,339	$ 450,307	$ 484,433	$ 445,168	$ 442,649	$ 467,891	$ 452,417	$ 387,256	1,811,247	1,750,213	$ 1,322,060
Goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,555,393	1,580,997
Services transferred over time
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									63,191	55,776
Revenues from contracts with customers
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,618,584	1,636,773
Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,555,393	1,580,997
Other									192,663	113,440
Total revenues									1,748,056	1,694,437	1,267,275
Marketing | Goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,555,393	1,580,997
Marketing | Services transferred over time
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Marketing | Revenues from contracts with customers
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,555,393	1,580,997
Transportation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									63,191	55,776
Other									0	0
Total revenues									63,191	55,776	$ 53,358
Transportation | Goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Transportation | Services transferred over time
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									63,191	55,776
Transportation | Revenues from contracts with customers
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									$ 63,191	$ 55,776

Revenue Recognition - Other Rev

Revenue Recognition - Other Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Total revenues from contracts with customers	$ 1,618,584	$ 1,636,773
Accounting Standards Update 2014-09 | Revenue gross-up
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Total revenues from contracts with customers	$ 859,091	$ 448,846	$ 203,095

Subsidiary Bankruptcy, Decons_2

Subsidiary Bankruptcy, Deconsolidation and Sale (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Aug. 01, 2017	Apr. 30, 2017	Apr. 25, 2017
Subsidiary Bankruptcy and Deconsolidation [Line Items]
Loss on deconsolidation of subsidiary				$ 0	$ 0	$ 3,505
Proceeds from sales of AREC assets				0	0	$ 2,775
Accounts receivable – related party				0	$ 425
AREC
Subsidiary Bankruptcy and Deconsolidation [Line Items]
Loss on deconsolidation of subsidiary			$ 1,600
Proceeds from sales of AREC assets	$ 2,800			1,000
DIP financing amount arranged									$ 1,250
DIP amount outstanding		$ 400
AREC | LIBOR
Subsidiary Bankruptcy and Deconsolidation [Line Items]
DIP financing, interest rate									2.00%
AREC | Disposal Group, Held-for-sale, Not Discontinued Operations
Subsidiary Bankruptcy and Deconsolidation [Line Items]
Expected transaction price			$ 5,000				$ 5,200	$ 5,000
Gain (loss) on disposal		$ (1,900)		$ 600

Prepayments and Other Current_3

Prepayments and Other Current Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Insurance premiums	$ 473	$ 677
Rents, licenses and other	1,086	880
Total	$ 1,559	$ 1,557

Property and Equipment - Cost o

Property and Equipment - Cost of Property and Equipment and Related Accumulated Depreciaiton, Depletion, and Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Property and equipment gross under finance leases	$ 164,244
Property and equipment, gross		$ 139,441
Less accumulated depreciation, depletion and amortization under finance leases	(95,198)
Less accumulated depreciation, depletion and amortization		(94,818)
Property and equipment, net under finance leases	69,046
Property and equipment, net	69,046	44,623
Depreciation, depletion and amortization	16,641	10,654	$ 13,599
Amortization of property and equipment under finance leases	1,807
Marketing
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	$ 8,741	6,384	7,812
Minimum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	2 years
Maximum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	39 years
Tractors and trailers
Property, Plant and Equipment [Line Items]
Property and equipment gross under finance leases	$ 115,693
Property and equipment, gross		96,523
Tractors and trailers | Minimum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	5 years
Tractors and trailers | Maximum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	6 years
Field equipment
Property, Plant and Equipment [Line Items]
Property and equipment gross under finance leases	$ 25,094
Property and equipment, gross		20,725
Less accumulated depreciation, depletion and amortization under finance leases	(700)
Field equipment | Marketing
Property, Plant and Equipment [Line Items]
Property and equipment gross under finance leases	$ 3,300
Field equipment | Minimum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	2 years
Field equipment | Maximum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	5 years
Buildings
Property, Plant and Equipment [Line Items]
Property and equipment gross under finance leases	$ 16,055
Property and equipment, gross		15,746
Buildings | Minimum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	5 years
Buildings | Maximum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	39 years
Office equipment
Property, Plant and Equipment [Line Items]
Property and equipment gross under finance leases	$ 1,951
Property and equipment, gross		1,863
Office equipment | Minimum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	2 years
Office equipment | Maximum
Property, Plant and Equipment [Line Items]
Property and equipment, useful life	5 years
Land
Property, Plant and Equipment [Line Items]
Property and equipment gross under finance leases	$ 1,790
Property and equipment, gross		1,790
Construction in progress
Property, Plant and Equipment [Line Items]
Property and equipment gross under finance leases	3,661
Property and equipment, gross		2,794
Tractors
Property, Plant and Equipment [Line Items]
Property and equipment gross under finance leases	5,500
Property and equipment, gross		4,700
Less accumulated depreciation, depletion and amortization under finance leases	(1,700)
Less accumulated depreciation, depletion and amortization		(700)
Assets not held under finance leases
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	14,833
Assets not held under capital leases
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization		10,112	13,478
Assets held under finance leases
Property, Plant and Equipment [Line Items]
Amortization of property and equipment under finance leases	$ 1,808
Assets held under capital leases
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization		$ 542	$ 121

Property and Equipment - Sales

Property and Equipment - Sales of Equipment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Trucks
Property, Plant and Equipment [Line Items]
Gains on sales of used tractors, trailers and equipment	$ 1,400	$ 1,240	$ 594

Property and Equipment - Asset

Property and Equipment - Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO liability at beginning of year	$ 1,525	$ 1,273	$ 2,329
Liabilities incurred	17	252	18
Accretion of discount	48	36	58
Liabilities settled	(17)	(36)	(261)
Deconsolidation of subsidiary	0	0	(871)
ARO liability at end of year	$ 1,573	$ 1,525	$ 1,273

Asset Acquisition - Additional

Asset Acquisition - Additional Information (Details)	May 06, 2019USD ($)trucktrailer$ / sharesshares	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Schedule of Asset Acquisition [Line Items]
Cash		$ 5,624,000	$ 10,272,000	$ 0
EH Trucking
Schedule of Asset Acquisition [Line Items]
Payments for asset acquisitions	$ 6,447,000
Cash	$ 5,624,000
Number of shares | shares	11,145
Number of tractor trailer trucks | truck	39
Number of trailers | trailer	51
Transaction costs	$ 100,000
Share price (USD per share) | $ / shares	$ 35.15
Liabilities assumed	$ 0
Maximum quarterly payment	146,875
Contingent consideration arrangements, range of outcomes, value, low	0
Contingent consideration arrangements, range of outcomes, value, high	$ 587,500
Contingent consideration, accrual		200,000
EH Trucking | Customer Relationships
Schedule of Asset Acquisition [Line Items]
Useful life	7 years
Amortization of intangible assets		$ 200,000

Asset Acquisition - Considerati

Asset Acquisition - Consideration Paid and Amortization Expense (Details) - USD ($) $ in Thousands	May 06, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Consideration:
Cash		$ 5,624	$ 10,272	$ 0
Recognized amounts of identifiable assets acquired:
Property and equipment — tractors and trailers		35,743	$ 11,731	$ 2,644
EH Trucking
Consideration:
Cash	$ 5,624
Value of AE common shares issued	392
Contingent consideration arrangement	431
Fair value of total consideration transferred	6,447
Recognized amounts of identifiable assets acquired:
Property and equipment — tractors and trailers	4,576
Shop, office and telecommunication equipment	20
Intangible assets — customer relationships	1,851
Total purchase price	$ 6,447
Amortization expense
2020		302
2021		283
2022		263
2023		244
2024		$ 227

Asset Acquisition - Red River (

Asset Acquisition - Red River (Details) - Red River $ in Thousands	Oct. 01, 2018USD ($)trucktrailer
Business Acquisition [Line Items]
Cash payment for acquisition	$ 10,000
Number of tractor trailer trucks | truck	113
Number of trailers | trailer	126
Acquisition related costs	$ 300
Purchase price	10,300
Purchase Price Allocation
Tractors	4,799
Trailers	4,901
Field equipment	381
Materials and supplies	191
Total purchase price	$ 10,272

Cash Deposits and Other Asset_2

Cash Deposits and Other Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Insurance collateral deposits	$ 1,233	$ 1,453
Excess loss fund	943	1,916
Accumulated interest income	609	788
State collateral deposits	37	57
Materials and supplies	477	443
Total	$ 3,299	$ 4,657

Investments in Unconsolidated_2

Investments in Unconsolidated Affiliates (Details) - USD ($)	1 Months Ended				3 Months Ended		12 Months Ended
	Dec. 31, 2017	Feb. 28, 2017	Apr. 30, 2016	Jan. 31, 2016	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Impairment of investments in unconsolidated affiliates							$ 0	$ 0	$ 2,500,000
Loss on deconsolidation of subsidiary							0	0	3,505,000
Proceeds from sales of AREC assets							0	0	$ 2,775,000
Receivable							94,534,000	85,197,000
AREC
Schedule of Equity Method Investments [Line Items]
Loss on deconsolidation of subsidiary						$ 1,600,000
Proceeds from sales of AREC assets	$ 2,800,000						1,000,000
Receivable								$ 400,000
AREC | Disposal Group, Held-for-sale, Not Discontinued Operations
Schedule of Equity Method Investments [Line Items]
Gain (loss) on disposal					$ (1,900,000)		$ 600,000
Bencap LLC
Schedule of Equity Method Investments [Line Items]
Maximum borrowing amount				$ 1,500,000
Income tax benefit										$ 800,000
Percentage of equity method investment							0.00%
VestaCare, Inc.
Schedule of Equity Method Investments [Line Items]
Voting interest			3.00%
Impairment of investments in unconsolidated affiliates					$ 2,500,000
Percentage of equity method investment			15.00%				15.00%
Bencap LLC
Schedule of Equity Method Investments [Line Items]
Voting interest				30.00%
Cash payment for acquisition				$ 2,200,000
Recognized net loss from investment										1,400,000
Impairment of investments in unconsolidated affiliates										1,700,000
Losses from equity investment										$ 500,000
Additional funding request		$ 500,000
VestaCare, Inc.
Schedule of Equity Method Investments [Line Items]
Cash payment for acquisition			$ 2,500,000

Segment Reporting - Information

Segment Reporting - Information Concerning Business Activities (Details) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2019USD ($)segment	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment									3
Revenues	$ 431,339	$ 450,307	$ 484,433	$ 445,168	$ 442,649	$ 467,891	$ 452,417	$ 387,256	$ 1,811,247	$ 1,750,213	$ 1,322,060
Operating earnings (losses)									7,800	1,408	1,502
Depreciation, depletion and amortization									16,641	10,654	13,599
Property and equipment additions									35,743	11,731	2,644
Inventory liquidation gains and valuation (losses)					(7,900)					(7,900)
Voluntary early retirement program expense											400
Property and equipment acquired under capital leases									4,148	2,898	1,808
Leasehold Improvements
Segment Reporting Information [Line Items]
Property and equipment additions									22	13
Marketing
Segment Reporting Information [Line Items]
Revenues									1,748,056	1,694,437	1,267,275
Depreciation, depletion and amortization									8,741	6,384	7,812
Property and equipment additions									7,249	1,540	468
Inventory liquidation gains and valuation (losses)	$ 3,700				$ (5,400)				3,700	(5,400)	3,300
Transportation
Segment Reporting Information [Line Items]
Revenues									63,191	55,776	53,358
Depreciation, depletion and amortization									7,900	4,270	5,364
Property and equipment additions									28,472	10,178	351
Oil and Gas and Other
Segment Reporting Information [Line Items]
Revenues									0	0	1,427
Depreciation, depletion and amortization									0	0	423
Property and equipment additions									22	13	1,825
Operating Segments
Segment Reporting Information [Line Items]
Operating earnings (losses)									17,998	10,345	11,209
Operating Segments | Marketing
Segment Reporting Information [Line Items]
Operating earnings (losses)									16,099	7,008	11,700
Operating Segments | Transportation
Segment Reporting Information [Line Items]
Operating earnings (losses)									1,899	3,337	(544)
Operating Segments | Oil and Gas and Other
Segment Reporting Information [Line Items]
Operating earnings (losses)									$ 0	$ 0	$ 53

Segment Reporting - Reconciliat

Segment Reporting - Reconciliation of Segment Earnings to Earnings Before Income Taxes (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating earnings (losses)	$ 7,800	$ 1,408	$ 1,502
General and administrative	(10,198)	(8,937)	(9,707)
Loss on deconsolidation of subsidiary	0	0	(3,505)
Impairment of investment in unconsolidated affiliate	0	0	(2,500)
Gain on dissolution of investment	573	0	0
Interest income	2,766	2,155	1,103
Interest expense	(636)	(109)	(27)
(Losses) earnings before income taxes	10,503	3,454	(3,427)
Voluntary early retirement program expense			400
Selling and Administrative Expenses
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Voluntary early retirement program expense			1,000
Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating earnings (losses)	17,998	10,345	11,209
Segment Reconciling Items
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Loss on deconsolidation of subsidiary	0	0	(3,505)
Impairment of investment in unconsolidated affiliate	0	0	(2,500)
Gain on dissolution of investment	573	0	0
Interest income	2,766	2,155	1,103
Interest expense	$ (636)	$ (109)	$ (27)

Segment Reporting - Identifiabl

Segment Reporting - Identifiable Assets by Industry Segment (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Assets	$ 330,842	$ 278,870
Operating Segments
Segment Reporting Information [Line Items]
Assets	330,842	278,870	$ 282,704
Operating Segments | Marketing
Segment Reporting Information [Line Items]
Assets	141,402	119,370	134,745
Operating Segments | Transportation
Segment Reporting Information [Line Items]
Assets	58,483	34,112	29,069
Operating Segments | Oil and natural gas
Segment Reporting Information [Line Items]
Assets	0	0	425
Corporate, Non-Segment
Segment Reporting Information [Line Items]
Assets	$ 130,957	$ 125,388	$ 118,465

Transactions with Affiliates (D

Transactions with Affiliates (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Interest income on DIP financing			$ 100
Affiliated Entities
Related Party Transaction [Line Items]
Affiliate billings to us	$ 83	$ 75	81
Billings to affiliates	5	6	4
Rentals paid to affiliate	487	487	583
Fees paid to Bencap	$ 0	$ 0	$ 108

Derivative Instruments and Fa_3

Derivative Instruments and Fair Value Measurements - Narrative (Details) - Commodity Contract	12 Months Ended
	Dec. 31, 2019barrel_of_oil_per_daycontract	Dec. 31, 2018barrel_of_oil_per_daycontract
Derivative [Line Items]
Number of contracts held | contract	6	10
January 2020 through February 2020
Derivative [Line Items]
Production per day	258
March 2020 through April 2020
Derivative [Line Items]
Production per day	322
May 2020 through December 2020
Derivative [Line Items]
Production per day	258
January through April 2019
Derivative [Line Items]
Production per day		322
May 2019
Derivative [Line Items]
Production per day		258
June 2019 through August 2019
Derivative [Line Items]
Production per day		322
September 2019 through December 2019
Derivative [Line Items]
Production per day		258

Derivative Instruments and Fa_4

Derivative Instruments and Fair Value Measurements - Use of Derivative Instruments (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Derivative, Fair Value, Net [Abstract]
As reported fair value contracts	$ 0	$ 162
As reported fair value contracts	0	139
Commodity Contract | Not Designated as Hedging Instrument | Current Assets
Derivative, Fair Value, Net [Abstract]
Asset derivatives:	0	162
Liability derivatives:	0	0
Less counterparty offsets	0	0
As reported fair value contracts	0	162
Commodity Contract | Not Designated as Hedging Instrument | Other Assets
Derivative, Fair Value, Net [Abstract]
Asset derivatives:	0	0
Liability derivatives:	0	0
Less counterparty offsets	0	0
As reported fair value contracts	0	0
Commodity Contract | Not Designated as Hedging Instrument | Current Liabilities
Derivative, Fair Value, Net [Abstract]
Asset derivatives:	0	0
Liability derivatives:	0	139
Less counterparty offsets	0	0
As reported fair value contracts	0	139
Commodity Contract | Not Designated as Hedging Instrument | Other Liabilities
Derivative, Fair Value, Net [Abstract]
Asset derivatives:	0	0
Liability derivatives:	0	0
Less counterparty offsets	0	0
As reported fair value contracts	$ 0	$ 0

Derivative Instruments and Fa_5

Derivative Instruments and Fair Value Measurements - Forward Month Commodity Contracts (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Commodity Contract | Revenues - Marketing | Not Designated as Hedging Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Revenues – Marketing	$ (24)	$ 2	$ (26)

Derivative Instruments and Fa_6

Derivative Instruments and Fair Value Measurements - Derivatives by Hedging Relationship and Fair Value Measurements (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Derivatives:
Current assets	$ 0	$ 162
Current assets, counterparty offsets	0	0
Current liabilities	0	(139)
Current liabilities, counterparty offsets	0	0
Net value	0	23
Net value, counterparty offsets	0	0
Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1)
Derivatives:
Current assets	0	0
Current liabilities	0	0
Net value	0	0
Significant Unobservable Inputs (Level 2)
Derivatives:
Current assets	0	162
Current liabilities	0	(139)
Net value	0	23
Significant Unobservable Inputs (Level 3)
Derivatives:
Current assets	0	0
Current liabilities	0	0
Net value	$ 0	$ 0

Derivative Instruments and Fa_7

Derivative Instruments and Fair Value Measurements - Nonrecurring Fair Value Measurements (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-cash impairment loss	$ 0	$ 0	$ 3,505
Fair Value, Measurements, Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-cash impairment loss			6,005
Fair Value, Measurements, Nonrecurring | AREC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			425
Non-cash impairment loss			3,505
Fair Value, Measurements, Nonrecurring | VestaCare, Inc.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			0
Non-cash impairment loss			2,500
Fair Value, Measurements, Nonrecurring | Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1) | AREC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			0
Fair Value, Measurements, Nonrecurring | Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1) | VestaCare, Inc.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			0
Fair Value, Measurements, Nonrecurring | Significant Unobservable Inputs (Level 2) | AREC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			425
Fair Value, Measurements, Nonrecurring | Significant Unobservable Inputs (Level 2) | VestaCare, Inc.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			0
Fair Value, Measurements, Nonrecurring | Significant Unobservable Inputs (Level 3) | AREC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			0
Fair Value, Measurements, Nonrecurring | Significant Unobservable Inputs (Level 3) | VestaCare, Inc.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments			$ 0

Income Taxes - Components of th

Income Taxes - Components of the Company's Income Tax (Provision) Benefit (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Current:
Federal	$ 164	$ 388	$ (1,418)
State	(375)	39	523
Total current	(211)	427	(895)
Deferred:
Federal	(2,063)	(752)	3,722
State	(22)	(184)	118
Total deferred	(2,085)	(936)	3,840
Total (provision for) benefit from income taxes	$ (2,296)	$ (509)	$ 2,945

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Taxes Computed at the Corporate Federal Income Tax Rate to the Reported Income Tax (provision) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Pre-tax net book income (loss)	$ 10,503	$ 3,454	$ (3,427)
Statutory federal income tax (provision) benefit	(2,206)	(725)	1,165
State income tax (provision) benefit	(397)	(145)	736
Federal statutory depletion	0	0	153
Federal tax rate adjustment	0	0	2,007
Valuation allowance	0	98	(1,038)
Return to provision adjustments	285	388	0
Other	22	(125)	(78)
Total (provision for) benefit from income taxes	$ (2,296)	$ (509)	$ 2,945
Effective income tax rate	22.00%	15.00%	86.00%
Effective income tax rate excluding adjustment		26.00%	58.00%

Income Taxes - Components of _2

Income Taxes - Components of the Federal Deferred Tax Asset (Liability) (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Long-term deferred tax asset (liability) [Abstract]
Deferred Tax Assets, Prepaid and Other Insurance	$ 248
Prepaid and other insurance		$ (170)
Property	(9,953)	(5,259)
Investments in unconsolidated affiliates	525	525
Valuation allowance related to investments in unconsolidated affiliates	(525)	(525)
Net operating loss	(3,567)	(1,436)
Other	(184)	(245)
Net long-term deferred tax liability	(6,322)	(4,238)
Net deferred tax liability	$ (6,322)	$ (4,238)

Income Taxes - Earliest Tax Yea

Income Taxes - Earliest Tax Years Remaining for Federal and Major States of Operations (Details)	12 Months Ended
	Dec. 31, 2019
Federal
Income Tax Examination [Line Items]
Earliest Open Tax Year	2015
Texas
Income Tax Examination [Line Items]
Earliest Open Tax Year	2015
Louisiana
Income Tax Examination [Line Items]
Earliest Open Tax Year	2016
Michigan
Income Tax Examination [Line Items]
Earliest Open Tax Year	2015

Income Taxes - Other Matters (D

Income Taxes - Other Matters (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)
Income Tax Disclosure [Abstract]
Tax benefit from remeasurement of deferred tax liabilities	$ 2

Share-Based Compensation Plan_2

Share-Based Compensation Plan (Details) - USD ($)	3 Months Ended	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	May 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense in connection with equity-based awards		$ 478,000	$ 255,000	$ 0
The 2018 LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized (in shares)	120,827	120,827			150,000
Accrued dividends	$ 23,600	$ 23,600	$ 9,500
The 2018 LTIP | Restricted stock units awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights, percentage		33.00%
Number of Shares
Beginning balance (in shares)		13,733	0
Granted (in shares)		14,376	13,733
Vested (in shares)		(7,188)	0
Forfeited (in shares)		(2,139)	0
Ending balance (in shares)	18,782	18,782	13,733	0
Weighted Average Grant Date Fair Value per Share
Beginning balance (in dollars per share)			$ 0
Granted (in dollars per share)		34	43
Vested (in dollars per share)		41.90	0
Forfeited (in dollars per share)		$ 38.42	0
Ending balance (in dollars per share)				$ 0
Aggregate grant date fair value awards issues		$ 500,000	$ 600,000
Unrecognized compensation cost	$ 300,000	$ 300,000
Period for recognition for remaining compensation cost		1 year 4 months 24 days
The 2018 LTIP | Performance share unit awards
Number of Shares
Beginning balance (in shares)		3,966	0
Granted (in shares)		8,094	7,932
Performance factor decrease (in shares)		(7,312)	(3,966)
Vested (in shares)		(416)	0
Forfeited (in shares)		(1,545)	0
Ending balance (in shares)	2,787	2,787	3,966	0
Weighted Average Grant Date Fair Value per Share
Beginning balance (in dollars per share)			$ 0
Granted (in dollars per share)		$ 34	43
Performance factor decrease (in dollars per share)		34.23	43
Vested (in dollars per share)		43	0
Forfeited (in dollars per share)		$ 37.37	$ 0
Ending balance (in dollars per share)				$ 0
Aggregate grant date fair value awards issues		$ 300,000	$ 200,000
Unrecognized compensation cost	$ 100,000	$ 100,000
Award vesting period		3 years
Performance factor	0.00%	100.00%	47.50%
Period for recognition for remaining compensation cost		1 year 4 months 24 days
The 2018 LTIP | Performance share unit awards | Plan
Weighted Average Grant Date Fair Value per Share
Performance factor			100.00%

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Supplemental Cash Flow Elements [Abstract]
Cash paid for interest	$ 636	$ 109	$ 22
Cash paid for federal and state income taxes	234	787	459
Non-cash transactions:
Change in accounts payable related to property and equipment	(448)	1,685	70
Property and equipment acquired under capital leases	4,148	2,898	1,808
Issuance of common shares in asset acquisition (see Note 7)	392	0	0
Receivable for sale of property and equipment	$ 952	$ 0	$ 0

Leases (Details)

Leases (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
Leases [Abstract]
Operating lease, liability	$ 9,575	$ 11,400
Lease, Cost [Abstract]
Amortization of ROU assets	1,807
Interest on lease liabilities	295
Operating lease cost	2,933
Short-term lease cost	9,627
Total lease expense	14,662
Cash paid for amounts included in measurement of lease liabilities:
Operating cash flows from operating leases	2,934
Operating cash flows from finance leases	295
Financing cash flows from finance leases	1,697
ROU assets obtained in exchange for new lease liabilities:
Finance leases	4,148
Operating leases	$ 12,006
Weighted-average remaining lease term (years):
Finance leases	3 years 10 days
Operating leases	4 years 9 months 10 days
Weighted-average discount rate:
Finance leases	4.90%
Operating leases	5.00%
Assets and Liabilities
Finance lease, ROU assets	$ 6,384
Operating lease right-of-use assets, net	9,576
Current portion of finance lease obligations	2,167		$ 883
Operating lease, liability, current	2,252
Finance lease, liability, noncurrent	4,376		3,209
Operating lease, liability, noncurrent	7,323
Finance Lease
2020	2,426
2021	2,426
2022	1,492
2023	642
2024	37
Thereafter	0
Total lease payments	7,023
Less: Interest	(480)
Present value of lease liabilities	6,543
Less: Current portion of lease obligation	(2,167)		(883)
Total long-term lease obligation	4,376		3,209
Operating Lease
2020	2,660
2021	2,256
2022	1,914
2023	1,776
2024	1,668
Thereafter	443
Total lease payments	10,717
Less: Interest	(1,142)
Present value of lease liabilities	9,575	$ 11,400
Less: Current portion of lease obligation	(2,252)
Total long-term lease obligation	$ 7,323
Finance Lease
2019			1,052
2020			1,052
2021			1,052
2022			909
2023			451
Thereafter			0
Total lease payments			4,516
Less: Interest			(424)
Present value of lease liabilities			4,092
Less: Current portion of lease obligation			(883)
Total long-term lease obligation			3,209
Operating Lease
2019			4,242
2020			2,258
2021			2,107
2022			1,782
2023			1,495
Thereafter			1,488
Total			$ 13,372
Minimum
Lessee, Lease, Description [Line Items]
Leases, weighted average remaining lease term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Leases, weighted average remaining lease term	8 years

Commitments and Contingencies -

Commitments and Contingencies - Schedule of Expenses and Losses Incurred but not Reported (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Pre-funded premiums for losses incurred but not reported	$ 168	$ 427
Accrued automobile and workers’ compensation claims	$ 2,956	$ 2,246

Commitments and Contingencies_2

Commitments and Contingencies - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Aug. 15, 2019
Commitments and Contingencies Disclosure [Abstract]
Umbrellas insurance coverage	$ 1
Aggregate medical claims for umbrella insurance coverage per calendar year	9.6
Estimate of possible loss		$ 1.2
Parental guaranteed obligations	$ 44.3

Commitments and Contingencies_3

Commitments and Contingencies - Schedule of Accrued Medical Claims (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Accrued medical claims	$ 1,016	$ 1,181

Concentration of Credit Risk (D

Concentration of Credit Risk (Details)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Concentration Risk [Line Items]
Percentage of U.S. demand supplied by company	1.00%
Customer Concentration Risk | Revenues
Concentration Risk [Line Items]
Concentration risk, percentage	50.00%
Customer Concentration Risk | Revenues | Customer One
Concentration Risk [Line Items]
Concentration risk, percentage	37.30%	27.30%	22.80%
Customer Concentration Risk | Revenues | Customer Two
Concentration Risk [Line Items]
Concentration risk, percentage	11.40%	14.10%	17.10%
Customer Concentration Risk | Revenues | Customer Three
Concentration Risk [Line Items]
Concentration risk, percentage			10.80%
Customer Concentration Risk | Revenues | Customer Four
Concentration Risk [Line Items]
Concentration risk, percentage			10.70%
Customer Concentration Risk | Accounts Receivable | Customer One
Concentration Risk [Line Items]
Concentration risk, percentage	16.60%	18.40%	19.10%
Customer Concentration Risk | Accounts Receivable | Customer Two
Concentration Risk [Line Items]
Concentration risk, percentage	12.60%	11.90%	15.00%
Customer Concentration Risk | Accounts Receivable | Customer Three
Concentration Risk [Line Items]
Concentration risk, percentage			11.10%
Customer Concentration Risk | Accounts Receivable | Customer Four
Concentration Risk [Line Items]
Concentration risk, percentage			10.40%

Quarterly Financial Informati_3

Quarterly Financial Information (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Selected quarterly financial data and earnings per share [Abstract]
Revenues	$ 431,339	$ 450,307	$ 484,433	$ 445,168	$ 442,649	$ 467,891	$ 452,417	$ 387,256	$ 1,811,247	$ 1,750,213	$ 1,322,060
Operating (losses) earnings	2,887	303	(643)	5,253	(6,206)	2,239	4,298	1,077
Net (losses) earnings	$ 2,653	$ 640	$ 6	$ 4,908	$ (3,848)	$ 2,035	$ 3,620	$ 1,138	$ 8,207	$ 2,945	$ (482)
Earnings (losses) per share:
Basic earnings (losses) per share (in dollars per share)	$ 0.63	$ 0.15	$ 0	$ 1.16	$ (0.91)	$ 0.48	$ 0.86	$ 0.27	$ 1.94	$ 0.70	$ (0.11)
Diluted net (losses) earnings per share (in dollars per share)	$ 0.63	$ 0.15	$ 0	$ 1.16	$ (0.91)	$ 0.48	$ 0.86	$ 0.27	$ 1.94	$ 0.70	$ (0.11)
Inventory adjustments					$ 7,900					$ 7,900

Oil and Gas Producing Activit_3

Oil and Gas Producing Activities (Unaudited) - Cost Incurred in Oil and Gas Exploration and Development Activities (Details) $ in Thousands	4 Months Ended
	Apr. 30, 2017USD ($)
Property acquisition costs:
Unproved	$ 4
Exploration costs:
Expensed	5
Development costs	1,815
Total costs incurred	$ 1,824

Oil and Gas Producing Activit_4

Oil and Gas Producing Activities (Unaudited) - Proved Developed and Undeveloped Oil and Gas Reserves (Details) bbl in Thousands, MMcf in Thousands	4 Months Ended
	Apr. 30, 2017bblMMcf
Natural Gas
Total proved reserves:
Beginning of year | MMcf	4,214
Crude oil and natural gas reserves sold | MMcf	(4,067)
Extensions, discoveries and other reserve additions | MMcf	42
Production | MMcf	(189)
End of year | MMcf	0
Crude Oil
Total proved reserves:
Beginning of year | bbl	187
Crude oil and natural gas reserves sold | bbl	(170)
Extensions, discoveries and other reserve additions | bbl	6
Production | bbl	(23)
End of year | bbl	0

Oil and Gas Producing Activit_5

Oil and Gas Producing Activities (Unaudited) - Narrative (Details)	12 Months Ended
	Dec. 31, 2018
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Period of average estimated price of proved reserves	12 months

Oil and Gas Producing Activit_6

Oil and Gas Producing Activities (Unaudited) - Principal Sources of Changes in the Standardized Measure of Discounted Future Net Flows (Details) $ in Thousands	4 Months Ended
	Apr. 30, 2017USD ($)
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of year	$ 2,260
Sale of crude oil and natural gas reserves	(2,732)
New field discoveries and extensions, net of future production costs	94
Sales of crude oil and natural gas produced, net of production costs	(476)
Accretion of discount	130
Production rate changes and other	(493)
Net change in income taxes	1,217
End of year	$ 0

Oil and Gas Producing Activit_7

Oil and Gas Producing Activities (Unaudited) - Results of Operations for Oil and Gas Producing Activities (Details) $ in Thousands	4 Months Ended
	Apr. 30, 2017USD ($)
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Revenues	$ 1,427
Costs and expenses:
Production	(951)
Depreciation, depletion and amortization	(423)
Operating earnings (losses) before income taxes	53
Income tax benefit (expense)	(19)
Operating earnings (losses)	$ 34