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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D. C. 20549

FORM 10-Q
(Mark one)

þ   QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2018  

OR

o   TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ___  to  ___.

Commission file number: 1-07908

ADAMS RESOURCES & ENERGY, INC.
(Exact Name of Registrant as Specified in Its Charter)
Delaware
74-1753147
(State or Other Jurisdiction of
Incorporation or Organization)
(I.R.S. Employer
Identification No.)

17 South Briar Hollow Lane, Suite 100
Houston, Texas 77027
(Address of Principal Executive Offices, including Zip Code)
(713) 881-3600
(Registrant’s Telephone Number, including Area Code)

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes  þ No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer o
Accelerated filer þ
Non-accelerated filer o
Smaller reporting company o
Emerging growth company o
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

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

A total of 4,217,596 shares of Common Stock were outstanding at November 1, 2018. Our Common Stock trades on the NYSE American (formerly the NYSE MKT) under the ticker symbol “AE.”


ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
TABLE OF CONTENTS

Page No.



1
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except share data)

September 30,  December 31,
2018 2017
ASSETS 
Current assets: 
Cash and cash equivalents  $ 130,774  $ 109,393 
Accounts receivable, net of allowance for doubtful 
accounts of $208 and $303, respectively  108,662  121,353 
Inventory  34,760  12,192 
Derivative assets  263  166 
Income tax receivable  —  1,317 
Prepayments and other current assets  1,271  1,264 
Total current assets  275,730  245,685 
Property and equipment, net  30,918  29,362 
Investment in unconsolidated affiliate  425  425 
Cash deposits and other assets  6,239  7,232 
Total assets  $ 313,312  $ 282,704 
LIABILITIES AND SHAREHOLDERS’ EQUITY 
Current liabilities: 
Accounts payable  $ 146,895  $ 124,706 
Accounts payable – related party  6  5 
Derivative liabilities  247  145 
Current portion of capital lease obligations  568  338 
Other current liabilities  8,219  4,404 
Total current liabilities  155,935  129,598 
Other long-term liabilities: 
Asset retirement obligations  1,414  1,273 
Capital lease obligations  2,041  1,351 
Deferred taxes and other liabilities  2,655  3,363 
Total liabilities  162,045  135,585 
Commitments and contingencies (Note 12) 
Shareholders’ equity: 
Preferred stock – $1.00 par value, 960,000 shares 
authorized, none outstanding  —  — 
Common stock – $0.10 par value, 7,500,000 shares 
authorized, 4,217,596 shares outstanding  422  422 
Contributed capital  11,837  11,693 
Retained earnings  139,008  135,004 
Total shareholders’ equity  151,267  147,119 
Total liabilities and shareholders’ equity  $ 313,312  $ 282,704 

See Notes to Unaudited Condensed Consolidated Financial Statements.

2
ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except per share data)

Three Months Ended  Nine Months Ended 
September 30,  September 30, 
2018 2017 2018 2017
Revenues: 
Marketing  $ 453,626  $ 282,229  $ 1,266,055  $ 872,020 
Transportation  14,265  13,082  41,509  40,153 
Oil and natural gas  —  —  —  1,427 
Total revenues  467,891  295,311  1,307,564  913,600 
Costs and expenses: 
Marketing  449,367  277,906  1,250,233  860,567 
Transportation  12,412  12,668  36,603  36,681 
Oil and natural gas  —  —  —  951 
General and administrative  1,533  2,787  6,100  6,884 
Depreciation, depletion and amortization  2,340  3,240  7,014  10,772 
Total costs and expenses  465,652  296,601  1,299,950  915,855 
Operating earnings (losses)  2,239  (1,290) 7,614  (2,255)
Other income (expense): 
Loss on deconsolidation of subsidiary  —  (1,870) —  (3,505)
Impairment of investment in unconsolidated 
affiliate  —  (2,500) —  (2,500)
Interest income  601  370  1,486  789 
Interest expense  (26) (8) (60) (10)
Total other income (expense), net  575  (4,008) 1,426  (5,226)
(Losses) earnings before income taxes  2,814  (5,298) 9,040  (7,481)
Income tax benefit (provision)  (779) 2,265  (2,247) 3,306 
Net (losses) earnings  $ 2,035  $ (3,033) $ 6,793  $ (4,175)
Earnings (losses) per share: 
Basic net (losses) earnings per common share  $ 0.48  $ (0.72) $ 1.61  $ (0.99)
Diluted net (losses) earnings per common share  $ 0.48  $ (0.72) $ 1.61  $ (0.99)
Dividends per common share  $ 0.22  $ 0.22  $ 0.66  $ 0.66 


See Notes to Unaudited Condensed Consolidated Financial Statements.
3
ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)

Nine Months Ended
September 30, 
2018 2017
Operating activities: 
Net (losses) earnings  $ 6,793  $ (4,175)
Adjustments to reconcile net (losses) earnings to net cash 
provided by operating activities: 
Depreciation, depletion and amortization  7,014  10,772 
Gains on sales of property  (890) (347)
Impairment of oil and natural gas properties  —  3 
Provision for doubtful accounts  (95) (9)
Stock-based compensation expense  144  — 
Deferred income taxes  (685) (1,198)
Net change in fair value contracts  5  48 
Impairment of investment in unconsolidated affiliate  —  2,500 
Loss on deconsolidation of subsidiary  —  3,505 
Changes in assets and liabilities: 
Accounts receivable  12,830  5,228 
Accounts receivable/payable, affiliates  1  266 
Inventories  (22,568) (9,328)
Income tax receivable  1,317  (1,412)
Prepayments and other current assets  (7) 927 
Accounts payable  22,254  9,482 
Accrued liabilities  3,815  465 
Other  (103) (240)
Net cash provided by operating activities  29,825  16,487 
Investing activities: 
Property and equipment additions  (7,756) (2,465)
Proceeds from property sales  1,314  430 
Insurance and state collateral (deposits) refunds  1,070  439 
Net cash used in investing activities  (5,372) (1,596)
Financing activities: 
Principal repayments of capital lease obligations  (288) — 
Dividends paid on common stock  (2,784) (2,784)
Net cash used in financing activities  (3,072) (2,784)
Increase in cash and cash equivalents  21,381  12,107 
Cash and cash equivalents at beginning of period  109,393  87,342 
Cash and cash equivalents at end of period  $ 130,774  $ 99,449 


See Notes to Unaudited Condensed Consolidated Financial Statements.

4
ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY
(In thousands)

Total 
Common  Contributed  Retained  Shareholders’ 
Stock  Capital  Earnings  Equity 
Balance, January 1, 2018  $ 422  $ 11,693  $ 135,004  $ 147,119 
Net earnings  —  —  1,138  1,138 
Dividends declared: 
Common stock, $0.22/share  —  —  (928) (928)
Balance, March 31, 2018  422  11,693  135,214  147,329 
Net earnings  —  —  3,620  3,620 
Stock-based compensation expense  —  3  —  3 
Dividends declared: 
Common stock, $0.22/share  —  —  (928) (928)
Balance, June 30, 2018  422  11,696  137,906  150,024 
Net earnings  —  —  2,035  2,035 
Stock-based compensation expense  —  141  —  141 
Dividends declared: 
Common stock, $0.22/share  —  —  (928) (928)
Awards under LTIP, $0.22/share  —  —  (5) (5)
Balance, September 30, 2018 $ 422  $ 11,837  $ 139,008  $ 151,267 



Total 
Common  Contributed  Retained  Shareholders’ 
Stock  Capital  Earnings  Equity 
Balance, January 1, 2017  $ 422  $ 11,693  $ 139,197  $ 151,312 
Net losses  —  —  (860) (860)
Dividends declared: 
Common stock, $0.22/share  —  —  (928) (928)
Balance, March 31, 2017  422  11,693  137,409  149,524 
Net losses  —  —  (282) (282)
Dividends declared: 
Common stock, $0.22/share  —  —  (928) (928)
Balance, June 30, 2017  422  11,693  136,199  148,314 
Net losses  —  —  (3,033) (3,033)
Dividends declared: 
Common stock, $0.22/share  —  —  (928) (928)
Balance, September 30, 2017 $ 422  $ 11,693  $ 132,238  $ 144,353 



See Notes to Unaudited Condensed Consolidated Financial Statements.


5

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 1. 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 and 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 and ISO tank container storage and transportation 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.  

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 ISO tank container storage and transportation, and (iii) upstream crude oil and natural gas exploration and production. We exited the upstream crude oil and natural gas exploration and production business during 2017 with the sale of our upstream crude oil and natural gas exploration and production assets as a result of a voluntary bankruptcy filing for this subsidiary. The bankruptcy case involving the wholly owned subsidiary through which this business was conducted was dismissed in October 2018, and we expect final settlement to occur during the fourth quarter of 2018.  

Basis of Presentation

Our results of operations for the three and nine months ended September 30, 2018 are not necessarily indicative of results expected for the full year of 2018. In the opinion of management, the accompanying unaudited condensed consolidated financial statements reflect all adjustments consisting of normal recurring accruals necessary for fair presentation.  The condensed consolidated financial statements and the accompanying notes are prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) for interim financial statements and the rules of the U.S. Securities and Exchange Commission (“SEC”). Certain information and footnote disclosures required by GAAP for complete annual financial statements have been omitted and, therefore, these interim financial statements should be read in conjunction with our audited consolidated financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2017 (the “2017 Form 10-K”) filed with the SEC on March 12, 2018. 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 these condensed consolidated financial statements are appropriate, actual results could differ from those estimates.


6

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 2. Summary of Significant Accounting Policies

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 10 for further discussion).

A reconciliation of the denominator used in the calculation of basic and diluted earnings (losses) per share is as follows (in thousands, except per share data):
Three Months Ended
September 30,  		Nine Months Ended
September 30, 
2018 2017 2018 2017
Basic earnings (losses) per share: 
Net earnings (losses)  $ 2,035  $ (3,033) $ 6,793  $ (4,175)
Weighted average number of shares
outstanding — Basic  		4,218  4,218  4,218  4,218 
Basic earnings (losses) per share  $ 0.48  $ (0.72) $ 1.61  $ (0.99)
Diluted earnings (losses) per share: 
Net earnings (losses)  $ 2,035  $ (3,033) $ 6,793  $ (4,175)
Diluted weighted average number of
shares outstanding: 
Common shares  4,218  4,218  4,218  4,218 
Restricted stock unit awards (1)
1  —  —  — 
Performance share unit awards (2)
—  —  —  — 
Total  4,219  4,218  4,218  4,218 
Diluted earnings (losses) per share  $ 0.48  $ (0.72) $ 1.61  $ (0.99)
_______________
(1) The dilutive effect of restricted stock unit awards for the three and nine months ended September 30, 2018 is de minimis.
(2)  The dilutive effect of performance share awards will be included in the calculation of diluted earnings per share when the performance share award performance conditions have been achieved.

Fair Value Measurements

The carrying amounts reported in the unaudited condensed 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.

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.
7

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
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 current reporting periods (see Note 9 for further information).  

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 these items and their respective tax basis. 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.

Investments in Unconsolidated Affiliates

AREC . In April 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 seeking relief under Chapter 11 of Title 11 of the United States Code. As a result of the voluntary bankruptcy filing, we no longer controlled the operations of AREC; therefore, 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. 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 represents 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. At September 30, 2018, our remaining investment in AREC was $0.4 million. The bankruptcy case was dismissed during October 2018, and we expect final settlement to occur during the fourth quarter of 2018.

VestaCare . During the third quarter of 2017, we reviewed our investment in VestaCare, Inc. (“VestaCare”), in which we own an approximate 15 percent equity interest (less than 3 percent voting interest), and determined that the current projected operating results did not support the carrying value of the investment. As such, we recognized a pre-tax impairment charge of $2.5 million during the third quarter of 2017 and wrote-off our investment in VestaCare.

Letter of Credit Facility

We maintain a Credit and Security Agreement with Wells Fargo Bank, National Association to provide up to a $60.0 million stand-by letter of credit facility used to support crude oil purchases within our crude oil marketing segment and for other purposes. We are currently using the letter of credit facility for a letter of credit related to our insurance program. This facility is collateralized by the eligible accounts receivable within our crude oil marketing segment and expires on August 30, 2019.

The issued stand-by letters of credit are canceled as the underlying purchase obligations are satisfied by cash payment when due. The letter of credit facility places certain restrictions on GulfMark Energy, Inc., one of our wholly owned subsidiaries. These restrictions include the maintenance of positive net earnings excluding inventory valuation changes, as defined, among other restrictions. We are currently in compliance with all such financial covenants. Subsequent to September 30, 2018, per the terms of our letter of credit agreement, we were in default of certain nonfinancial covenants and obtained a waiver whereby the creditor will not exercise any of their rights or remedies. At September 30, 2018 and December 31, 2017, we had $0.4 million and $2.2 million, respectively, outstanding under this facility.  


8

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
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 ranging from two to thirty-nine years.

We review our long-lived assets for impairment whenever there is evidence that the carrying value of these assets may not be recoverable. Any impairment recognized is permanent and may not be restored. Property and equipment is reviewed at the lowest level of identifiable cash flows. For properties requiring impairment, the fair value is estimated based on an internal discounted cash flow model of future cash flows.

See Note 5 for additional information regarding our property and equipment.

Recent Accounting Developments

In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Codification (“ASC”) 842, Leases (“ASC 842”), which requires substantially all leases (with the exception of leases with a term of one year or less) to be recorded on the balance sheet using a method referred to as the right-of-use (“ROU”) asset approach. We plan to adopt the new standard on January 1, 2019 using the modified retrospective approach and apply it to (i) all new leases entered into after January 1, 2019 and (ii) all existing lease contracts as of January 1, 2019 through a cumulative adjustment to equity. In accordance with this approach, our consolidated operating expenses for periods prior to January 1, 2019 will not be revised.  

The new standard introduces two lease accounting models, which result in a lease being classified as either a “finance” or “operating” lease on the basis of whether the lessee effectively obtains control of the underlying asset during the lease term. A lease would be classified as a finance lease if it meets one of five classification criteria, four of which are generally consistent with current lease accounting guidance. By default, a lease that does not meet the criteria to be classified as a finance lease will be deemed an operating lease. Regardless of classification, the initial measurement of both lease types will result in the balance sheet recognition of a ROU asset representing a company’s right to use the underlying asset for a specified period of time and a corresponding lease liability. The lease liability will be recognized at the present value of the future lease payments, and the ROU asset will equal the lease liability adjusted for any prepaid rent, lease incentives provided by the lessor, and any indirect costs.

The subsequent measurement of each type of lease varies. Leases classified as a finance lease will be accounted for using the effective interest method. Under this approach, a lessee will amortize the ROU asset (generally on a straight-line basis in a manner similar to depreciation) and the discount on the lease liability (as a component of interest expense). Leases classified as an operating lease will result in the recognition of a single lease expense amount that is recorded on a straight-line basis (or another systematic basis, if more appropriate).

We are in the process of reviewing our lease agreements in light of the new guidance. We anticipate that this new lease guidance will result in changes to the way our operating leases are recorded, presented and disclosed in our consolidated financial statements. 


9

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Stock-Based Compensation

We measure all share-based payments, including the issuance of restricted stock units and performance share units 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 statement of operations based on the estimated fair value of those awards on the grant date and 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. See Note 10 for additional information regarding our 2018 LTIP.  


Note 3. 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 three and nine months ended September 30, 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.
10

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
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.  


11

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
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 
Three Months Ended September 30, 2018 
Revenues from contracts with customers  $ 424,061  $ 14,265  $ 438,326 
Other (1)
29,565  —  29,565 
Total revenues  $ 453,626  $ 14,265  $ 467,891 
Timing of revenue recognition: 
Goods transferred at a point in time  $ 424,061  $ —  $ 424,061 
Services transferred over time  —  14,265  14,265 
Total revenues from contracts with customers  $ 424,061  $ 14,265  $ 438,326 
Nine Months Ended September 30, 2018 
Revenues from contracts with customers  $ 1,203,511  $ 41,509  $ 1,245,020 
Other (1)
62,544  —  62,544 
Total revenues  $ 1,266,055  $ 41,509  $ 1,307,564 
Timing of revenue recognition: 
Goods transferred at a point in time  $ 1,203,511  $ —  $ 1,203,511 
Services transferred over time  —  41,509  41,509 
Total revenues from contracts with customers  $ 1,203,511  $ 41,509  $ 1,245,020 
_______________
(1) Other 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 Marketing Revenue

Certain of the commodity purchase and sale contracts utilized by our crude oil marketing business 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):
Three Months Ended  Nine Months Ended 
September 30,  September 30, 
2018 2017 2018 2017
Revenue gross-up  $ 76,373  $ 46,306  $ 178,399  $ 148,779 



12

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 4. Prepayments and Other Current Assets

The components of prepayments and other current assets were as follows at the dates indicated (in thousands):
September 30,  December 31,
2018 2017
Insurance premiums  $ 274  $ 425 
Rents, licenses and other  997  839 
Total  $ 1,271  $ 1,264 


Note 5. 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  September 30,  December 31,
in Years  2018 2017
Tractors and trailers ( 1)
5 – 6  $ 84,578  $ 88,065 
Field equipment  2 – 5  19,987  18,490 
Buildings  5 – 39  15,746  15,727 
Office equipment  2 – 5  1,808  1,929 
Land  1,790  1,790 
Construction in progress  1,664  275 
Total  125,573  126,276 
Less accumulated depreciation  (94,655) (96,914)
Property and equipment, net  $ 30,918  $ 29,362 
_______________
(1) Amounts include assets held under capital leases for certain tractors in our marketing segment. Gross property and equipment associated with assets held under capital leases were $3.0 million and $1.8 million at September 30, 2018 and December 31, 2017, respectively. Accumulated amortization associated with assets held under capital leases were $0.4 million and $0.1 million at September 30, 2018 and December 31, 2017, respectively (see Note 12 for further information).

Components of depreciation, depletion and amortization expense were as follows for the periods indicated (in thousands):
Three Months Ended  Nine Months Ended 
September 30,  September 30, 
2018 2017 2018 2017
Depreciation, depletion and amortization, 
excluding amounts under capital leases  $ 2,210  $ 3,210  $ 6,703  $ 10,742 
Amortization of property and equipment 
under capital leases  130  30  311  30 
Total depreciation, depletion and amortization  $ 2,340  $ 3,240  $ 7,014  $ 10,772 


13

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 6. Cash Deposits and Other Assets

Components of cash deposits and other assets were as follows at the dates indicated (in thousands):

September 30,  December 31,
2018 2017
Amounts associated with liability insurance program: 
Insurance collateral deposits  $ 3,517  $ 3,767 
Excess loss fund  1,662  2,284 
Accumulated interest income  736  814 
Other amounts: 
State collateral deposits  61  57 
Materials and supplies  227  273 
Other  36  37 
Total  $ 6,239  $ 7,232 

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.


Note 7. 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 ISO tank container storage and transportation 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, and as a result of our loss of control of the wholly owned subsidiary, AREC was deconsolidated and is accounted for under the cost method of accounting. AREC remained a reportable segment until its deconsolidation, effective April 30, 2017.

14

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Information concerning our various business activities was as follows for the periods indicated (in thousands):
Reporting Segments 
Marketing  Transportation  Oil and Gas and Other  Total 
Three Months Ended September 30, 2018 
Revenues  $ 453,626  $ 14,265  $ —  $ 467,891 
Segment operating (losses) earnings  (1)
2,982  790  —  3,772 
Depreciation, depletion and amortization  1,277  1,063  —  2,340 
Property and equipment additions  (2)
612  4,416  —  5,028 
Three Months Ended September 30, 2017 
Revenues  $ 282,229  $ 13,082  $ —  $ 295,311 
Segment operating (losses) earnings  (1) ( 4 )
2,412  (915) —  1,497 
Depreciation, depletion and amortization  1,911  1,329  —  3,240 
Property and equipment additions (2)
178  179  —  357 
Nine Months Ended September 30, 2018 
Revenues  $ 1,266,055  $ 41,509  $ —  $ 1,307,564 
Segment operating (losses) earnings  (1)
11,712  2,002  —  13,714 
Depreciation, depletion and amortization  4,110  2,904  —  7,014 
Property and equipment additions  (2) (3)
1,682  6,061  13  7,756 
Nine Months Ended September 30, 2017 
Revenues  $ 872,020  $ 40,153  $ 1,427  $ 913,600 
Segment operating (losses) earnings  (1) ( 4 )
5,496  (920) 53  4,629 
Depreciation, depletion and amortization  5,957  4,392  423  10,772 
Property and equipment additions (2)
451  189  1,825  2,465 
_______________
(1) Our marketing segment’s operating earnings included inventory liquidation gains of $0.1 million and $2.5 million for the three and nine months ended September 30, 2018, respectively, inventory valuation gains of $2.0 million for the three months ended September 30, 2017 and inventory valuation losses of $0.1 million for the nine months ended September 30, 2017.
(2) Our marketing segment’s property and equipment additions do not include approximately $1.2 million and $1.8 million  of tractors acquired during the nine months ended September 30, 2018 and 2017, respectively, under capital leases. See Note 12 for further information. 
(3) During the nine months ended September 30, 2018, we had $13 thousand of property and equipment additions for leasehold improvements at our corporate headquarters level, which is not attributed or allocated to any of our reporting segments.
(4) Segment operating (losses) earnings for the three and nine months ended September 30, 2017 included approximately $0.4 million of costs related to a voluntary early retirement program that was implemented in August 2017.


15

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
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):
Three Months Ended
September 30,  		Nine Months Ended
September 30, 
2018 2017 2018 2017
Segment operating earnings  $ 3,772  $ 1,497  $ 13,714  $ 4,629 
General and administrative  (1)
(1,533) (2,787) (6,100) (6,884)
Operating earnings (losses)  2,239  (1,290) 7,614  (2,255)
Loss on deconsolidation of subsidiary  —  (1,870) —  (3,505)
Impairment of investment in unconsolidated 
affiliate  —  (2,500) —  (2,500)
Interest income  601  370  1,486  789 
Interest expense  (26) (8) (60) (10)
(Losses) earnings before income taxes  $ 2,814  $ (5,298) $ 9,040  $ (7,481)
_______________
(1) General and administrative expenses for the three and nine months ended September 30, 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):

September 30,  December 31,
2018 2017
Reporting segment: 
Marketing  $ 143,427  $ 134,745 
Transportation  32,049  29,069 
Oil and Gas (1)
425  425 
Cash and other assets  137,411  118,465 
Total assets  $ 313,312  $ 282,704 
_______________
(1) Amounts represent our cost method investment in this segment.

Intersegment sales are 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.


Note 8. 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 from an affiliated entity.

We utilize our former affiliate, Bencap LLC (“Bencap”), to administer certain of our employee medical benefit programs including a detail audit of individual medical claims. Bencap earns 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.

16

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Activities with affiliates were as follows for the periods indicated (in thousands):

Three Months Ended  Nine Months Ended 
September 30,  September 30, 
2018 2017 2018 2017
Affiliate billings to us  $ 18  $ 16  $ 58  $ 52 
Billings to affiliates  1  1  4  3 
Rentals paid to affiliate  121  137  365  462 
Fees paid to Bencap (1)
—  —  —  108 
_______________
(1) Amount represents fees paid to Bencap through the date of the forfeiture of our investment during the first quarter of 2017. As a result of the investment forfeiture, Bencap is no longer an affiliate.


Note 9. Derivative Instruments and Fair Value Measurements

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 material 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.

At September 30, 2018, we had in place 12 commodity purchase and sale contracts, of which four of these contracts had 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 October 2018 through December 2018;
• 322 barrels per day of crude oil during January 2019 through April 2019;
• 258 barrels per day of crude oil during May 2019; and
• 322 barrels per day of crude oil during June 2019 through August 2019.
17

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
The estimated fair value of forward month commodity contracts (derivatives) reflected in the accompanying unaudited condensed consolidated balance sheet were as follows at the date indicated (in thousands):

September 30, 2018
Balance Sheet Location and Amount 
Current  Other  Current  Other 
Assets  Assets  Liabilities  Liabilities 
Asset derivatives: 
Fair value forward hydrocarbon commodity 
contracts at gross valuation  $ 263  $ —  $ —  $ — 
Liability derivatives: 
Fair value forward hydrocarbon commodity 
contracts at gross valuation  —  —  247  — 
Less counterparty offsets  —  —  —  — 
As reported fair value contracts  $ 263  $ —  $ 247  $ — 

At December 31, 2017, we had in place 20 commodity purchase and sale contracts, of which four of these contracts had 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:
• 452 barrels per day of crude oil during January 2018;
• 322 barrels per day of crude oil during February 2018 through May 2018;
• 258 barrels per day of crude oil during June 2018;
• 646 barrels per day of crude oil during July 2018;
• 322 barrels per day of crude oil during August 2018 through September 2018; and
• 258 barrels per day of crude oil during October 2018 through December 2018.
The estimated fair value of forward month commodity contracts (derivatives) reflected in the accompanying unaudited condensed consolidated balance sheet were as follows at the date indicated (in thousands):

December 31, 2017
Balance Sheet Location and Amount 
Current  Other  Current  Other 
Assets  Assets  Liabilities  Liabilities 
Asset derivatives: 
Fair value forward hydrocarbon commodity 
contracts at gross valuation  $ 166  $ —  $ —  $ — 
Liability derivatives: 
Fair value forward hydrocarbon commodity 
contracts at gross valuation  —  —  145  — 
Less counterparty offsets  —  —  —  — 
As reported fair value contracts  $ 166  $ —  $ 145  $ — 

18

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
We only enter into commodity contracts with creditworthy counterparties and evaluate our exposure to significant counterparties on an ongoing basis. At September 30, 2018 and December 31, 2017, 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 unaudited condensed consolidated statements of operations were as follows for the periods indicated (in thousands):

Gains (losses) 
Three Months Ended  Nine Months Ended 
September 30,  September 30, 
2018 2017 2018 2017
Revenues – marketing  $ (7) $ (748) $ (5) $ (48)


Fair Value Measurements

The following tables set forth, 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):

September 30, 2018
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 
Derivatives: 
Current assets  $ —  $ 263  $ —  $ —  $ 263 
Current liabilities  —  (247) —  —  (247)
Net value  $ —  $ 16  $ —  $ —  $ 16 

December 31, 2017
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 
Derivatives: 
Current assets  $ —  $ 166  $ —  $ —  $ 166 
Current liabilities  —  (145) —  —  (145)
Net value  $ —  $ 21  $ —  $ —  $ 21 


19

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
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 September 30, 2018 and December 31, 2017, 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. We had no items requiring nonrecurring fair value measurements during the nine months ended September 30, 2018. The following table presents categories of long-lived assets that were subject to nonrecurring fair value measurements during the nine months ended September 30, 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
September 30, and Liabilities Inputs Inputs Impairment
2017 (Level 1) (Level 2) (Level 3) Loss
Oil and gas properties — 
Investment in AREC $ 3,200  $ —  $ 3,200  $ —  $ 3,505 
Investment in VestaCare —  —  —  —  2,500 
$ 6,005 



Note 10.  Share-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 were granted during the second quarter of 2018. 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 share-based compensation to eligible employees and directors in June 2018. After giving effect to awards granted under the 2018 LTIP and assuming the potential achievement of the maximum amounts of the performance factors through September 30, 2018, a total of 120,403 shares were available for issuance. During the three and nine months ended September 30, 2018, we recognized $0.1 million and $0.1 million, respectively, of compensation expense in connection with equity-based awards as the grant date for all awards under the 2018 LTIP was June 29, 2018.


20

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
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 September 30, 2018, we had $5 thousand 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 September 30, 2018  13,733  $ — 
_______________
(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.

Unrecognized compensation cost associated with restricted stock unit awards was approximately $0.5 million at September 30, 2018. 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 1.6 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. The performance goals were 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 years after grant date, and are non-vested until the required service period expires.

21

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
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 will be 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 
Vested  —  $ — 
Forfeited  —  $ — 
Performance share unit awards at September 30, 2018  7,932  $ — 
_______________
(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 $0.4 million based on a grant date market price of our common share of $43.00 per share and assuming a performance factor of 100 percent.

Unrecognized compensation cost associated with performance share unit awards was approximately $0.3 million at September 30, 2018. We expect to recognize the remaining compensation cost for these awards over a weighted-average period of 2.9 years.


Note 11. Supplemental Cash Flow Information

Supplemental cash flows and non-cash transactions were as follows for the periods indicated (in thousands):
Nine Months Ended 
September 30, 
2018 2017
Cash paid for interest  $ 60  $ 10 
Cash paid for federal and state income taxes  811  381 
Non-cash transactions: 
Change in accounts payable related to property and equipment additions  (84) — 
Property and equipment acquired under capital leases  1,208  1,808 



22

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 12. Commitments and Contingencies

Capital Lease Obligations

During 2017 and 2018, we entered into capital leases for certain of our tractors in our crude oil marketing segment. The following table summarizes our principal contractual commitments outstanding under our capital leases at September 30, 2018 for the next five years, and in total thereafter (in thousands):

Remainder of 2018  $ 168 
2019 671 
2020 671 
2021 670 
2022 527 
Thereafter  158 
Total minimum lease payments  2,865 
Less: Amount representing interest  (256)
Present value of capital lease obligations  2,609 
Less current portion of capital lease obligations  (568)
Total long-term capital lease obligations  $ 2,041 

Operating Lease Obligations

We lease certain property and equipment under noncancelable and cancelable operating leases. Our significant lease agreements consist of (i) arrangements with independent truck owner-operators for use of their equipment and driver services; (ii) leased office space; and (iii) certain lease and terminal access contracts in order to provide tank storage and dock access for our crude oil marketing business. Currently, our significant lease agreements have terms that range from one to eight years.

Lease expense is charged to operating costs and expenses on a straight-line basis over the period of expected economic benefit. Contingent rental payments are expensed as incurred. We are generally required to perform routine maintenance on the underlying leased assets. Maintenance and repairs of leased assets resulting from our operations are charged to expense as incurred. Rental expense was as follows for the periods indicated (in thousands):
Three Months Ended  Nine Months Ended 
September 30, September 30,
2018 2017 2018 2017
Rental expense  $ 2,869  $ 2,874  $ 8,291  $ 9,332 


23

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
At September 30, 2018, rental obligations under non-cancelable operating leases and terminal arrangements with terms in excess of one year for the next five years and thereafter are payable as follows (in thousands):

Remainder of 2018  $ 1,536 
2019 3,551 
2020 1,780 
2021 1,651 
2022 1,570 
Thereafter  2,966 
Total operating lease payments  $ 13,054 

Insurance Policies

Under our automobile and workers’ compensation insurance policies that were in place through September 30, 2017, we pre-funded our estimated losses, 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 table below. If the potential insurance claims do not further develop, the pre-funded premiums will be returned to us as a premium refund.

Effective October 1, 2017, we changed the structure of our automobile and workers’ compensation insurance policies. We exited the group captive and now establish a liability for expected claims incurred but not reported on a monthly basis as we move forward. As claims are paid, the liability is relieved. The amount of pre-funded insurance premiums left to cover potential future losses and our accruals for automobile and workers’ compensation claims were as follows at the dates indicated (in thousands):
September 30,  December 31, 
2018 2017
Pre-funded premiums for losses incurred but not reported  $ 497  $ 988 
Accrued automobile and workers’ compensation claims  1,721  450 

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 annual aggregate medical claims exceeding $6.0 million. Medical accrual amounts were as follows at the dates indicated (in thousands):
September 30,  December 31, 
2018 2017
Accrued medical claims  $ 1,100  $ 1,329 

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 or results of operations.

24

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 13. Subsequent Event

On October 1, 2018, we completed the purchase of a trucking company for $10.0 million that owned approximately 113 tractor trailer trucks and 125 trailers operating in the Red River area in North Texas and South Central Oklahoma. This acquisition will be included in our crude oil marketing segment.   


25
Item 2 .  Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following information should be read in conjunction with our Unaudited Condensed Consolidated Financial Statements and accompanying Notes included in this quarterly report on Form 10-Q and the Audited Consolidated Financial Statements and related Notes, together with our discussion and analysis of financial position and results of operations, included in our annual report on Form 10-K for the year ended December 31, 2017 (the “2017 Form 10-K”), as filed on March 12, 2018 with the U.S. Securities and Exchange Commission (“SEC”).  Our financial statements have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”).


Cautionary Statement Regarding Forward-Looking Information

This quarterly report on Form 10-Q contains various forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”) and information that are based on our beliefs, as well as assumptions made by us and information currently available to us. When used in this document, words such as “anticipate,” “project,” “expect,” “plan,” “seek,” “goal,” “estimate,” “forecast,” “intend,” “could,” “should,” “would,” “will,” “believe,” “may,” “potential” and similar expressions and statements regarding our plans and objectives for future operations are intended to identify forward-looking statements. Although we believe that our expectations reflected in such forward-looking statements are reasonable, we cannot give any assurances that such expectations will prove to be correct.  Forward-looking statements are subject to a variety of risks, uncertainties and assumptions as described in more detail under Part I, Item 1A of our 2017 Form 10-K and within Part II, Item 1A of this quarterly report.  If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, our actual results may vary materially from those anticipated, estimated, projected or expected.  You should not put undue reliance on any forward-looking statements.  The forward-looking statements in this quarterly report speak only as of the date hereof.  Except as required by federal and state securities laws, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or any other reason.


Overview of Business

Adams Resources & Energy, Inc. (“AE”), a Delaware corporation organized in 1973, and its 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 and ISO tank container storage and transportation 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.  

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 ISO tank container storage and transportation and (iii) upstream crude oil and natural gas exploration and production. We exited the upstream crude oil and natural gas exploration and production business during 2017 with the sale of our upstream crude oil and natural gas exploration and production assets as a result of a voluntary bankruptcy filing for this subsidiary. The bankruptcy case involving the wholly owned subsidiary through which this business was conducted was dismissed in October 2018, and we expect final settlement to occur during the fourth quarter of 2018.



26
Recent Developments

On October 1, 2018, we completed the purchase of a trucking company for $10.0 million that owned approximately 113 tractor trailer trucks and 125 trailers operating in the Red River area in North Texas and South Central Oklahoma. This acquisition will be included in our crude oil marketing segment.  


Results of Operations

Marketing

Our crude oil marketing segment revenues, operating earnings and selected costs were as follows for the periods indicated (in thousands):
Three Months Ended  Nine Months Ended 
September 30,  September 30, 
2018 2017
Change (1)
2018 2017
Change (1)
Revenues  $ 453,626  $ 282,229  61  % $ 1,266,055  $ 872,020  45  %
Operating earnings  2,982  2,412  24  % 11,712  5,496  113  %
Depreciation and amortization  1,277  1,911  (33) % 4,110  5,957  (31) %
Driver commissions  3,099  2,962  5  % 9,155  9,153  —  %
Insurance  1,435  1,358  6  % 3,849  3,855  — %
Fuel  1,479  1,249  18  % 4,647  3,887  20  %
_______________
(1) Represents the percentage increase (decrease) from the prior year period.

Volume and price information were as follows for the periods indicated:

Three Months Ended  Nine Months Ended 
September 30, September 30,
2018 2017 2018 2017
Field level purchase volumes – per day (1)
Crude oil – barrels  70,635  64,104  68,767  65,760 
Average purchase price 
Crude oil – per barrel  $ 71.69  $ 46.78  $ 68.11  $ 47.38 
_______________
(1) Reflects the volume purchased from third parties at the field level of operations.

Revenues and Operating Earnings . Crude oil marketing revenues increased by $171.4 million during the three months ended September 30, 2018 as compared to the three months ended September 30, 2017, primarily as a result of an increase in the market price of crude oil, which increased revenues by approximately $129.5 million, and higher overall crude oil volumes, which increased revenues by approximately $41.9 million. The average crude oil price received was $46.78 for the three months ended September 30, 2017, which increased to $71.69 for the three months ended September 30, 2018.

Our crude oil marketing operating earnings for the three months ended September 30, 2018 increased by $0.6 million as compared to the same period in 2017, due to increased crude oil volumes and improved market conditions.  Operating earnings were also impacted by inventory valuation changes (as shown in the table below).


27
Crude oil marketing revenues increased by $394.0 million during the nine months ended September 30, 2018 as compared to the nine months ended September 30, 2017, primarily as a result of an increase in the market price of crude oil, which increased revenues by approximately $338.7 million, and higher overall crude oil volumes, which increased revenues by approximately $55.3 million. The average crude oil price received was $47.38 for the nine months ended September 30, 2017, which increased to $68.11 for the nine months ended September 30, 2018.

Our crude oil marketing operating earnings for the nine months ended September 30, 2018 increased by $6.2 million as compared to the same period in 2017, due to increased crude oil volumes and improved market conditions. Operating earnings were also impacted by inventory valuation changes.

Expenses . Driver commissions increased by $0.1 million during the three months ended September 30, 2018 as compared to the same period in 2017, primarily due to increased driver pay and an increase in crude oil marketing volumes, partially offset by a decrease in the number of drivers in the 2018 period as compared to the 2017 period. Insurance costs were mostly consistent with the same period in 2017, primarily as a result of higher insurance claims in the 2018 period, offset by decreased mileage during the 2018 period as compared to the 2017 period, and favorable driver safety performance during the 2018 period. Fuel costs increased by $0.2 million during the three months ended September 30, 2018 as compared to the same period in 2017, consistent with higher crude oil prices during the 2018 period and an increase in the price of diesel fuel during the 2018 period as compared to the 2017 period. Depreciation and amortization expense decreased by $0.6 million during the three months ended September 30, 2018 as compared to the same period in 2017, primarily as a result of certain tractors, trailers and field equipment being fully depreciated during 2017.

Driver commissions during the nine months ended September 30, 2018 were consistent with the same period in 2017, with increased driver pay and an increase in crude oil marketing volumes, offset by a decrease in the number of drivers in the 2018 period as compared to the 2017 period. Insurance costs were consistent with the same period in 2017, primarily as a result of decreased mileage during the 2018 period as compared to the 2017 period, and favorable driver safety performance during the 2018 period, offset by higher insurance claims. Fuel costs increased by $0.8 million during the nine months ended September 30, 2018 as compared to the same period in 2017 consistent with higher crude oil prices during the 2018 period and an increase in the price of diesel fuel during the 2018 period as compared to the 2017 period. Depreciation and amortization expense decreased by $1.8 million during the nine months ended September 30, 2018 as compared to the same period in 2017, primarily as a result of certain tractors, trailers and field equipment being fully depreciated during 2017.

Field Level Operating Earnings (Non-GAAP Financial Measure) . Inventory valuations and forward commodity contract (derivatives or mark-to-market) valuations are two significant factors affecting comparative crude oil marketing segment operating earnings. As a purchaser and shipper of crude oil, we hold inventory in storage tanks and third-party pipelines. During periods of increasing crude oil prices, we recognize inventory liquidation gains while during periods of falling prices, we recognize inventory liquidation and valuation losses.

Crude oil marketing operating earnings can be affected by the valuations of our forward month commodity contracts (derivative instruments). These non-cash valuations are calculated and recorded at each period end based on the underlying data existing as of such date. We generally enter into these derivative contracts as part of a pricing strategy based on crude oil purchases at the wellhead (field level). The valuation of derivative instruments at period end requires the recognition of non-cash “mark-to-market” gains and losses.


28
The impact of inventory liquidations and derivative valuations on our crude oil marketing segment operating earnings is summarized in the following reconciliation of our non-GAAP financial measure for the periods indicated (in thousands):
Three Months Ended  Nine Months Ended 
September 30, September 30,
2018 2017 2018 2017
As reported segment operating earnings (1)
$ 2,982  $ 2,412  $ 11,712  $ 5,496 
Add (subtract): 
Inventory liquidation gains  (60) (1,954) (2,535) — 
Inventory valuation losses  —  —  —  109 
Derivative valuation losses  7  748  5  48 
Field level operating earnings (2)
$ 2,929  $ 1,206  $ 9,182  $ 5,653 
_______________
(1) Segment operating earnings included inventory liquidation gains of $0.1 million and $2.5 million for the three and nine months ended September 30, 2018, respectively, inventory liquidation gains of $2.0 million for the three months ended September 30, 2017 and inventory valuation losses of $0.1 million for the nine months ended September 30, 2017.
(2) The use of field level operating earnings is unique to us, not a substitute for a GAAP measure and may not be comparable to any similar measures developed by industry participants. We utilize this data to evaluate the profitability of our operations.

Field level operating earnings and field level purchase volumes depict our day-to-day operation of acquiring crude oil at the wellhead, transporting the product and delivering the product to market sales point. Field level operating earnings increased during the three and nine months ended September 30, 2018 as compared to the same periods in 2017 due to an increase in the market price of crude oil, which increased revenues, the effects of lower barge costs, reduced operating expenses, increased crude oil volumes and improved market conditions.

We held crude oil inventory at a weighted average composite price as follows at the dates indicated (in barrels):
September 30, 2018 December 31, 2017
Average  Average 
Barrels  Price  Barrels  Price 
Crude oil inventory  476,703  $ 72.92  198,011  $ 61.57 

Historically, prices received for crude oil have been volatile and unpredictable with price volatility expected to continue. See “Part I, Item 1A. Risk Factors ” in our 2017 Form 10-K.


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Transportation

Our transportation segment revenues, operating earnings (losses) and selected costs were as follows for the periods indicated (in thousands):
Three Months Ended  Nine Months Ended 
September 30, September 30,
2018 2017
Change (1 )
2018 2017
Change (1)
Revenues  $ 14,265  $ 13,082  9  % $ 41,509  $ 40,153  3  %
Operating earnings (losses)  $ 790  $ (915) 186  % $ 2,002  $ (920) 318  %
Depreciation and amortization  $ 1,063  $ 1,329  (20) % $ 2,904  $ 4,392  (34) %
Driver commissions  $ 3,163  $ 2,912  9  % $ 8,769  $ 8,640  1  %
Insurance  $ 1,317  $ 1,598  (18) % $ 3,921  $ 4,051  (3) %
Fuel  $ 1,770  $ 1,582  12  % $ 5,368  $ 4,691  14  %
Maintenance expense  $ 1,221  $ 1,532  (20) % $ 4,296  $ 4,641  (7) %
Mileage (000s)  4,860  5,404  (10) % 14,629  16,647  (12) %
_______________
(1) Represents the percentage increase (decrease) from the prior year period.

Our revenue rate structure includes a component for fuel costs in which fuel cost fluctuations are largely passed through to the customer over time. Revenues, net of fuel cost, were as follows for the periods indicated (in thousands):
Three Months Ended  Nine Months Ended 
September 30, September 30,
2018 2017 2018 2017
Total transportation revenue  $ 14,265  $ 13,082  $ 41,509  $ 40,153 
Diesel fuel cost  (1,770) (1,582) (5,368) (4,691)
Revenues, net of fuel cost (1)
$ 12,495  $ 11,500  $ 36,141  $ 35,462 
_______________
(1) Revenues, net of fuel cost, is a non-GAAP financial measure and is utilized for internal analysis of the results of our transportation segment.

Transportation revenues increased by $1.2 million during the three months ended September 30, 2018 as compared to the three months ended September 30, 2017, primarily as a result of a new transportation agreement entered into in January 2018 and higher transportation rates in the 2018 period, partially offset by a decrease in revenue as a result of less miles traveled in the current period. Revenues, net of fuel cost, increased by $1.0 million during the three months ended September 30, 2018, primarily as a result of higher revenues in the 2018 period, partially offset by an increase in the price of diesel and lower miles traveled during the 2018 period. Transportation activity has continued to increase as we continue to pursue our strategy of streamlining operations and diversifying offerings in our transportation segment. We have continued to work with customers to increase our transportation rates as well as streamlining operations in low margin areas. This increase in services has resulted in an increase in revenues, an increase in variable expenses related to transportation activities and a decrease in mileage as we reduce low margin operations.

Fuel costs increased by $0.2 million as a result of an increase in the price of diesel during the 2018 period as compared to the 2017 period, partially offset by a decrease in miles traveled. Depreciation and amortization expense decreased by $0.3 million during the three months ended September 30, 2018 as compared to the same period in 2017, primarily as a result of certain tractors, trailers and field equipment being fully depreciated during 2017, partially offset by the purchase of new tractors in the the second and third quarters of 2018, which will result in increased depreciation expense in future periods.

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Transportation revenues increased by $1.4 million during the nine months ended September 30, 2018, primarily as a result of the new transportation agreement entered into in January 2018 and higher transportation rates in the 2018 period. Revenues, net of fuel cost, increased by $0.7 million during the nine months ended September 30, 2018, primarily as a result of higher revenues in the 2018 period, partially offset by an increase in the price of diesel fuel and lower miles traveled during the 2018 period. This increase in services resulted in an increase in variable expenses related to transportation activities.

Fuel costs increased by $0.7 million as a result of an increase in the price of diesel during the 2018 period as compared to the 2017 period, partially offset by a decrease in miles traveled. Depreciation and amortization expense decreased by $1.5 million during the nine months ended September 30, 2018 as compared to the same period in 2017, primarily as a result of certain tractors, trailers and field equipment being fully depreciated during 2017, partially offset by the purchase of new tractors in the second and third quarters of 2018, which will result in increased depreciation expense in future periods. During the remainder of 2018, we expect to purchase additional tractors, which will reduce the age of our fleet and increase depreciation expense. See “Other Items” below for further information regarding our purchase commitments.

Oil and Gas

Our upstream crude oil and natural gas exploration and production segment revenues and operating earnings were primarily a function of crude oil and natural gas prices and volumes. We accounted for our upstream operations under the successful efforts method of accounting. As a result of AREC’s bankruptcy filing in April 2017 and our loss of control of this subsidiary, we deconsolidated AREC effective with its bankruptcy filing in 2017 and recorded our investment in AREC under the cost method of accounting. Our results for the nine months ended September 30, 2017 were for the period in which AREC was consolidated (January 1, 2017 through April 30, 2017).

Our upstream crude oil and natural gas exploration and production segment revenues, operating earnings and depreciation and depletion expense were as follows for the nine months ended September 30, 2017 (in thousands):

Revenues  (1)
$ 1,427 
Operating earnings  ( 1 )
53 
Depreciation and depletion  (1)
423 
_______________
(1) Results for the nine months ended September 30, 2017 are only through April 30, 2017, as a result of the deconsolidation of this subsidiary due to its bankruptcy filing.


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Volume and price information were as follows for the nine months ended September 30, 2017 (volumes in thousands):  

Crude oil 
Volume – barrels (1)
11,643 
Average price per barrel  $ 49.44 
Natural gas 
Volume – Mcf (1)
189,488 
Average price per Mcf  $ 2.86 
Natural gas liquids 
Volume – barrels (1)
11,204 
Average price per barrel  $ 26.77 
_______________
(1) Volumes for the nine months ended September 30, 2017 are only through April 30, 2017, as a result of the deconsolidation of this subsidiary due to its bankruptcy filing.

General and Administrative Expense

General and administrative expense decreased by $1.3 million during the three months ended September 30, 2018 as compared to the same period in 2017 primarily due to the receipt in the 2018 period of approximately $0.6 million in insurance proceeds related to Hurricane Harvey insurance claims, which reduced expenses, and lower personnel costs in the 2018 period. The 2017 period also included approximately $1.0 million of additional personnel expenses related to a voluntary early retirement program for certain employees. These decreases in expenses were partially offset by an increase in expenses related to the amortization of equity awards (see Note 10 in the Notes to Condensed Consolidated Financial Statements) and an increase in outside service fees.  

General and administrative expense decreased by $0.8 million during the nine months ended September 30, 2018 as compared to the same period in 2017 primarily due to the receipt in the 2018 period of approximately $0.6 million in insurance proceeds related to Hurricane Harvey insurance claims, which reduced expenses, lower personnel costs in the 2018 period, and the reversal in the 2017 period of certain legal accruals of approximately $0.7 million related to legal matters. The 2017 period also included approximately $1.0 million of additional personnel expenses related to a voluntary early retirement program for certain employees. These decreases in expenses were partially offset by an increase in expenses related to the amortization of equity awards and an increase in legal and outside service fees in the 2018 period.

Investments in Unconsolidated Affiliates

AREC . In April 2017, we deconsolidated AREC effective with its bankruptcy filing on April 21, 2017 and recorded our investment in AREC 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. 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 represents the difference between the net proceeds we expect 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.

VestaCare . During the third quarter of 2017, we reviewed our investment in VestaCare, Inc. (“VestaCare”), in which we own an approximate 15 percent equity interest (less than 3 percent voting interest), and determined that the current projected operating results did not support the carrying value of the investment. As such, we recognized a pre-tax impairment charge of $2.5 million during the third quarter of 2017 and wrote-off our investment in VestaCare.

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Income Taxes

Provision for (benefit from) income taxes is based upon federal and state tax rates, and variations in amounts are consistent with taxable income (loss) in the respective accounting periods.

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. As a result of the lower tax rate, our provision for income taxes reflects the effects of the new tax rate during the three and nine months ended September 30, 2018 as compared to the same periods in 2017.

Outlook

We plan to operate our remaining business segments with internally generated cash flows during 2018, but intend to remain flexible as the focus will be on increasing efficiencies and on business development opportunities. During the remainder of 2018, we plan to leverage our investment in our transportation segment’s Houston terminal with the continued efforts to diversify service offerings, and we plan to grow in new or existing areas with our crude oil marketing segment, including integrating the acquisition that occurred on October 1, 2018 with our existing business (see Note 13 in the Notes to Unaudited Condensed Consolidated Financial Statements).


Liquidity and Capital Resources

Liquidity

Our liquidity is from our cash balance and net cash provided by operating activities and is therefore dependent on the success of future operations. If our cash inflow subsides or turns negative, we will evaluate our investment plan accordingly and remain flexible.

One of our wholly owned subsidiaries, AREC, filed for bankruptcy in April 2017. Over the past few years, 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. As a result of an auction process, AREC sold its assets for approximately $5.2 million during 2017. After settlement of certain claims in late 2017, AE received approximately $2.8 million from AREC in December 2017. AE anticipates receiving an additional $0.8 million cash payment from AREC in the fourth quarter of 2018 when the bankruptcy is settled.

At September 30, 2018 and December 31, 2017, we had no bank debt or other forms of debenture obligations. We maintain cash balances in order to meet the timing of day-to-day cash needs. Cash and working capital, the excess of current assets over current liabilities, were as follows at the dates indicated (in thousands):

September 30, December 31,
2018 2017
Cash and cash equivalents  $ 130,774  $ 109,393 
Working capital  119,795  116,087 

We maintain a stand-by letter of credit facility with Wells Fargo Bank, National Association to provide for the issuance of up to $60.0 million in stand-by letters of credit for the benefit of suppliers of crude oil within our crude oil marketing segment and for other purposes. Stand-by letters of credit are issued as needed and are canceled as the underlying purchase obligations are satisfied by cash payment when due. The issuance of stand-by letters of credit enables us to avoid posting cash collateral when procuring crude oil supply. We are currently using the letter of credit facility for a letter of credit related to our insurance program. At September 30, 2018 and December 31, 2017, we had $0.4 million and $2.2 million, respectively, outstanding under this facility.

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We believe current cash balances, together with expected cash generated from future operations, and the ease of financing truck and trailer additions through leasing arrangements (should the need arise) will be sufficient to meet our short-term and long-term liquidity needs. We expect to fund the $10.0 million purchase price of our Red River acquisition (see Note 13 in the Notes to Unaudited Condensed Consolidated Financial Statements) from our current cash balances.

We utilize cash from operations to make discretionary investments in our marketing and transportation businesses. With the exception of operating and capital lease commitments primarily associated with storage tank terminal arrangements, leased office space and tractors, our future commitments and planned investments can be readily curtailed if operating cash flows decrease. See “Other Items” below for information regarding our operating and capital lease obligations.

The most significant item affecting future increases or decreases in liquidity is earnings from operations, and these earnings are dependent on the success of future operations. See “Part I, Item 1A. Risk Factors ” in our 2017 Form 10-K.

Cash Flows from Operating, Investing and Financing Activities

Our consolidated cash flows from operating, investing and financing activities were as follows for the periods indicated (in thousands):
Nine Months Ended 
September 30,
2018 2017 
Cash provided by (used in): 
Operating activities  $ 29,825  $ 16,487 
Investing activities  (5,372) (1,596)
Financing activities  (3,072) (2,784)

Operating activities . Net cash flows provided by operating activities for the nine months ended September 30, 2018 increased by $13.3 million when compared to the same period in 2017. This increase was primarily due to an increase in revenues and the timing of collections of accounts receivable and payments of accounts payable, partially offset by a decrease in operating expenses.

At various times each month, we may make cash prepayments and/or early payments in advance of the normal due date to certain suppliers of crude oil within our crude oil marketing operations. Crude oil supply prepayments are recouped and advanced from month to month as the suppliers deliver product to us. In addition, in order to secure crude oil supply, we may also “early pay” our suppliers in advance of the normal payment due date of the twentieth of the month following the month of production. These “early payments” reduce cash and accounts payable as of the balance sheet date. We also require certain customers to make similar early payments or to post cash collateral with us in order to support their purchases from us. Early payments and cash collateral received from customers increases cash and reduces accounts receivable as of the balance sheet date.

Early payments were as follows at the dates indicated (in thousands):
September 30, December 31, 
2018 2017 
Early payments received  $ 38,459  $ 20,078 
Early payments to suppliers  1,100  6,100 


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We rely heavily on our ability to obtain open-line trade credit from our suppliers especially with respect to our crude oil marketing operations. During the fourth quarter of 2017 and during the third quarter of 2018, we elected to make several early payments in our crude oil marketing operations. Our cash balance increased by approximately $21.4 million as of September 30, 2018 relative to the year ended December 31, 2017 primarily as a result of the timing of the early payments and prepayments made and received during each period.

Investing activities . Net cash flows used in investing activities for the nine months ended September 30, 2018 increased by $3.8 million when compared to the same period in 2017. This increase was primarily due to an increase of $5.3 million in capital spending for property and equipment (see following table), partially offset by an increase of $0.9 million in cash proceeds from the sales of assets and an increase of $0.6 million in insurance and state collateral refunds.

Capital spending was as follows for the periods indicated (in thousands):
Nine Months Ended 
September 30,
2018 2017
Crude oil marketing  (1) (2)
$ 1,682  $ 451 
Truck transportation  ( 3 )
6,061  189 
Oil and natural gas exploration  —  1,825 
Other  13  — 
Capital spending  $ 7,756  $ 2,465 
_______________
(1) 2018 amount primarily relates to construction of a pipeline connection.
(2) Our marketing segment amounts do not include approximately $1.2 million and $1.8 million, respectively, of tractors acquired under capital leases.
(3) 2018 amount primarily relates to the purchase of 40 tractors, 31 of which were placed into service in June 2018 through September 2018. The remaining nine will be placed into service during the fourth quarter of 2018.

Financing activities . Cash used in financing activities for the nine months ended September 30, 2018 increased by $0.3 million when compared to the same period in 2017. During each of the nine months ended September 30, 2018 and 2017, we paid a quarterly cash dividend of $0.22 per common share, or a total of $2.8 million during each nine month period. During the 2018 period, we paid $0.3 million of principal repayments on capital lease obligations that we entered into in September 2017 and August 2018 for certain of our tractors in our crude oil marketing segment, with principal contractual commitments to be paid over a period of five years.  See “Other Items” below for further information regarding our capital leases.



35
Other Items

Contractual Obligations

The following table summarizes our significant contractual obligations at September 30, 2018 (in thousands):
Payments due by period 
Contractual Obligations  Total  Less than 1 year  1-3 years  3-5 years  More than 5 years 
Capital lease obligations (1)
$ 2,865  $ 671  $ 1,341  $ 853  $ — 
Operating lease obligations (2)
13,054  4,634  3,471  3,090  1,859 
Purchase obligations (3)
10,575  10,575  —  —  — 
Total contractual obligations  $ 26,494  $ 15,880  $ 4,812  $ 3,943  $ 1,859 
_______________
(1) Amounts represent our principal contractual commitments, including interest, outstanding under capital leases for certain tractors in our crude oil marketing segment.
(2) Amounts represent rental obligations under non-cancelable operating leases and terminal arrangements with terms in excess of one year.
(3) Amount represents commitments to purchase 61 new tractors and 20 new trailers in connection with our transportation business.

We maintain certain lease arrangements with independent truck owner-operators for use of their equipment and driver services on a month-to-month basis. In addition, we enter into office space and certain lease and terminal access contracts in order to provide tank storage and dock access for our crude oil marketing business. These storage and access contracts require certain minimum monthly payments for the term of the contracts. Rental expense was as follows for the periods indicated (in thousands):

Three Months Ended  Nine Months Ended 
September 30, September 30,
2018 2017 2018 2017
Rental expense  $ 2,869  $ 2,874  $ 8,291  $ 9,332 

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements that have or are reasonably expected to have a material current or future effect on our financial position, results of operations or cash flows.

Recent Accounting Pronouncements     

For information regarding recent accounting pronouncements, see Note 2 in the Notes to Unaudited Condensed Consolidated Financial Statements.

Related Party Transactions

For more information regarding related party transactions, see Note 8 in the Notes to Unaudited Condensed Consolidated Financial Statements.



36
Critical Accounting Policies and Use of Estimates

A discussion of our critical accounting policies and estimates is included in our 2017 Form 10-K. Certain of these accounting policies require the use of estimates. There have been no material changes to our accounting policies since the disclosures provided in our 2017 Form 10-K.


Item 3. Quantitative and Qualitative Disclosures about Market Risk

There have been no material changes to our “Quantitative and Qualitative Disclosures about Market Risk” that have occurred since the disclosures provided in our 2017 Form 10-K.


Item 4. Disclosure Controls and Procedures

As of the end of the period covered by this quarterly report, our management carried out an evaluation, with the participation of our Executive Chairman and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 and 15d-15(e) of the Exchange Act. Based on this evaluation, as of the end of the period covered by this quarterly report, our Executive Chairman and our Chief Financial Officer concluded:

(i) that our disclosure controls and procedures are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our principal executive and financial officers, as appropriate to allow for timely decisions regarding required disclosures; and

(ii) that our disclosure controls and procedures are effective.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(e) under the Exchange Act) during the fiscal quarter ended September 30, 2018, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.


PART II. OTHER INFORMATION

Item 1.   Legal Proceedings

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 or results of operations.



37
Item 1A. Risk Factors

In addition to the other information set forth in this Quarterly Report, you should carefully consider the risk factors and other cautionary statements described under the heading “Item 1A. Risk Factors” included in our 2017 Form 10-K and the risk factors and other cautionary statements contained in our other SEC filings, which could materially affect our businesses, financial condition or future results. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results. There have been no material changes in our Risk Factors from those disclosed in Item 1A of our 2017 Annual Report on Form 10-K or our other SEC filings.


Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

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Item 6. Exhibits

Exhibit
Number
Exhibit
3.1 
Certificate of Incorporation of Adams Resources & Energy, Inc., as amended (incorporated by reference to Exhibit 3(a) to Form 10-K for the fiscal year ended December 31, 1987).
3.2 
10.1*
31.1*
31.2*
32.1*
32.2*
101.CAL*
XBRL Calculation Linkbase Document
101.DEF*
XBRL Definition Linkbase Document
101.INS*
XBRL Instance Document — the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.LAB*
XBRL Labels Linkbase Document
101.PRE*
XBRL Presentation Linkbase Document
101.SCH*
XBRL Schema Document
____________
+ Management contract or compensation plan or arrangement.
*Filed or furnished (in the case of Exhibit 32.1 and 32.2) with this report.

39
SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

ADAMS RESOURCES & ENERGY, INC. 
(Registrant) 
Date: November 7, 2018 By:  /s/ Townes G. Pressler 
Townes G. Pressler 
Executive Chairman 
(Principal Executive Officer) 
By:  /s/ Tracy E. Ohmart 
Tracy E. Ohmart 
Chief Financial Officer 
(Principal Financial Officer and Principal 
Accounting Officer) 

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