AE 10-Q Quarterly Report March 31, 2018

ADAMS RESOURCES & ENERGY, INC.

10-Qs and 10-Ks

10-Q	Quarter ended Sept. 30, 2024
10-Q	Quarter ended June 30, 2024
10-Q	Quarter ended March 31, 2024
10-K	Fiscal year ended Dec. 31, 2023
10-Q	Quarter ended Sept. 30, 2023
10-Q	Quarter ended June 30, 2023
10-Q	Quarter ended March 31, 2023
10-K	Fiscal year ended Dec. 31, 2022
10-Q	Quarter ended Sept. 30, 2022
10-Q	Quarter ended June 30, 2022
10-Q	Quarter ended March 31, 2022
10-K	Fiscal year ended Dec. 31, 2021
10-Q	Quarter ended Sept. 30, 2021
10-Q	Quarter ended June 30, 2021
10-Q	Quarter ended March 31, 2021
10-K	Fiscal year ended Dec. 31, 2020
10-Q	Quarter ended Sept. 30, 2020
10-Q	Quarter ended June 30, 2020
10-Q	Quarter ended March 31, 2020
10-K	Fiscal year ended Dec. 31, 2019
10-Q	Quarter ended Sept. 30, 2019
10-Q	Quarter ended June 30, 2019
10-Q	Quarter ended March 31, 2019
10-K	Fiscal year ended Dec. 31, 2018
10-Q	Quarter ended Sept. 30, 2018
10-Q	Quarter ended June 30, 2018
10-Q	Quarter ended March 31, 2018
10-K	Fiscal year ended Dec. 31, 2017
10-Q	Quarter ended Sept. 30, 2017
10-Q	Quarter ended June 30, 2017
10-Q	Quarter ended March 31, 2017
10-K	Fiscal year ended Dec. 31, 2016
10-Q	Quarter ended Sept. 30, 2016
10-Q	Quarter ended June 30, 2016
10-Q	Quarter ended March 31, 2016
10-K	Fiscal year ended Dec. 31, 2015
10-Q	Quarter ended Sept. 30, 2015
10-Q	Quarter ended June 30, 2015
10-Q	Quarter ended March 31, 2015
10-K	Fiscal year ended Dec. 31, 2014
10-Q	Quarter ended Sept. 30, 2014
10-Q	Quarter ended May 27, 2014
10-Q	Quarter ended March 31, 2014
10-K	Fiscal year ended Dec. 31, 2013
10-Q	Quarter ended Sept. 30, 2013
10-Q	Quarter ended June 30, 2013
10-Q	Quarter ended March 31, 2013
10-K	Fiscal year ended Dec. 31, 2012
10-Q	Quarter ended Sept. 30, 2012
10-Q	Quarter ended June 30, 2012
10-Q	Quarter ended March 31, 2012
10-K	Fiscal year ended Dec. 31, 2011
10-Q	Quarter ended Sept. 30, 2011
10-Q	Quarter ended June 30, 2011
10-Q	Quarter ended March 31, 2011
10-K	Fiscal year ended Dec. 31, 2010
10-Q	Quarter ended Sept. 30, 2010
10-Q	Quarter ended June 30, 2010
10-Q	Quarter ended March 31, 2010
10-K	Fiscal year ended Dec. 31, 2009

PROXIES

DEF 14A	Filed on April 1, 2024
DEF 14A	Filed on April 3, 2023
DEF 14A	Filed on April 7, 2022
DEF 14A	Filed on April 1, 2021
DEF 14A	Filed on April 1, 2020
DEF 14A	Filed on April 5, 2019
DEF 14A	Filed on April 6, 2018
DEF 14A	Filed on April 11, 2017
DEF 14A	Filed on March 31, 2016
DEF 14A	Filed on March 26, 2015
DEF 14A	Filed on April 8, 2014
DEF 14A	Filed on March 29, 2012
DEF 14A	Filed on April 5, 2011
DEF 14A	Filed on May 13, 2010

10-Q 1 a1q201810-q.htm 10-Q 1Q 2018 Document

Table of Contents

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 March 31, 2018

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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes 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 (Do not check if a smaller reporting company)	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 May 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.
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements
	Unaudited Condensed Consolidated Balance Sheets	2
	Unaudited Condensed Consolidated Statements of Operations	3
	Unaudited Condensed Consolidated Statements Cash Flows	4
	Unaudited Condensed Consolidated Statements of Shareholders’ Equity	5
	Notes to Unaudited Condensed Consolidated Financial Statements	6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	21
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	30
Item 4.	Controls and Procedures	30

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	31
Item 1A.	Risk Factors	31
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	31
Item 3.	Defaults Upon Senior Securities	31
Item 4.	Mine Safety Disclosures	31
Item 5.	Other Information	31
Item 6.	Exhibits	32

Signatures		33

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)



	March 31,		December 31,
	2018		2017
ASSETS
Current assets:
Cash and cash equivalents	$	111,536	$	109,393
Accounts receivable, net of allowance for doubtful
accounts of $303 and $303, respectively	117,153		121,353
Inventory	19,267		12,192
Derivative assets	312		166
Income tax receivable	437		1,317
Prepayments and other current assets	1,111		1,264
Total current assets	249,816		245,685
Property and equipment, net	27,744		29,362
Investments in unconsolidated affiliates	425		425
Cash deposits and other assets	6,523		7,232
Total assets	$	284,508	$	282,704

LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	126,044	$	124,706
Accounts payable – related party	5		5
Derivative liabilities	289		145
Current portion of capital lease obligations	341		338
Other current liabilities	5,255		4,404
Total current liabilities	131,934		129,598
Other long-term liabilities:
Asset retirement obligations	1,334		1,273
Capital lease obligations	1,265		1,351
Deferred taxes and other liabilities	2,646		3,363
Total liabilities	137,179		135,585

Commitments and contingencies (Note 11)

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	11,693		11,693
Retained earnings	135,214		135,004
Total shareholders’ equity	147,329		147,119
Total liabilities and shareholders’ equity	$	284,508	$	282,704

See Notes to Unaudited Condensed Consolidated Financial Statements.

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)



	Three Months Ended
	March 31,
	2018			2017
Revenues:
Marketing	$	373,638		$	288,615
Transportation	13,618			13,455
Oil and natural gas	—			1,017
Total revenues	387,256			303,087

Costs and expenses:
Marketing	369,183			285,153
Transportation	12,301			12,162
Oil and natural gas	—			750
General and administrative	2,283			2,637
Depreciation, depletion and amortization	2,412			3,969
Total costs and expenses	386,179			304,671

Operating earnings (losses)	1,077			(1,584		)

Other income (expense):
Interest income	387			159
Interest expense	(19		)	(1		)
Total other income (expense), net	368			158

(Losses) earnings before income taxes	1,445			(1,426		)
Income tax benefit (provision)	(307		)	566

Net (losses) earnings	$	1,138		$	(860	)

Earnings (losses) per share:
Basic and diluted net (losses) earnings
per common share	$	0.27		$	(0.20	)

Weighted average number of common
shares outstanding	4,218			4,218

Dividends per common share	$	0.22		$	0.22

See Notes to Unaudited Condensed Consolidated Financial Statements.

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)



	Three Months Ended
	March 31,
	2018			2017
Operating activities:
Net (losses) earnings	$	1,138		$	(860	)
Adjustments to reconcile net (losses) earnings to net cash
provided by operating activities:
Depreciation, depletion and amortization	2,412			3,969
Gains (losses) on sales of property	(26		)	7
Impairment of oil and natural gas properties	—			3
Deferred income taxes	(709		)	60
Net change in fair value contracts	(2		)	(420		)
Changes in assets and liabilities:
Accounts receivable	4,200			(1,968		)
Inventories	(7,075		)	(7,557		)
Income tax receivable	880			(736		)
Prepayments and other current assets	153			744
Accounts payable	1,377			17,746
Accrued liabilities	851			1,084
Other	86			78
Net cash provided by operating activities	3,285			12,150

Investing activities:
Property and equipment additions	(866		)	(1,006		)
Proceeds from property sales	132			39
Insurance and state collateral (deposits) refunds	603			476
Net cash used in investing activities	(131		)	(491		)

Financing activities:
Principal repayments of capital lease obligations	(83		)	—
Dividends paid on common stock	(928		)	(928		)
Net cash used in financing activities	(1,011		)	(928		)

Increase in cash and cash equivalents	2,143			10,731
Cash and cash equivalents at beginning of period	109,393			87,342
Cash and cash equivalents at end of period	$	111,536		$	98,073

See Notes to Unaudited Condensed Consolidated Financial Statements.

Table of Contents

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 paid on common stock	—		—		(928		)	(928		)
Balance, March 31, 2018	$	422	$	11,693	$	135,214		$	147,329



								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 paid on common stock	—		—		(928		)	(928		)
Balance, March 31, 2017	$	422	$	11,693	$	137,409		$	149,524

See Notes to Unaudited Condensed Consolidated Financial Statements.

Table of Contents

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. We expect the bankruptcy case involving the wholly owned subsidiary through which this business was conducted to be dismissed during the second quarter of 2018.

Basis of Presentation

Our results of operations for the three months ended March 31, 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.

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 2. General Accounting and Disclosure Matters

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.

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).

Investments in Unconsolidated Affiliates

As a result of the voluntary bankruptcy filing in April 2017 of one of our wholly owned subsidiaries, Adams Resources Exploration Corporation (“AREC”), and our loss of control of AREC, we deconsolidated AREC in April 2017, and we recorded our investment in this subsidiary under the cost method of accounting. At March 31, 2018 , our remaining investment in AREC was $0.4 million . We expect the bankruptcy case to be dismissed during the second quarter of 2018.

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.

Letter of Credit Facility

We maintain a Credit and Security Agreement with Wells Fargo Bank, National Association to provide up to a $60 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 27, 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. At March 31, 2018 and December 31, 2017 , we had $0.4 million and $2.2 million , respectively, outstanding under this facility.

Table of Contents

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 of three to twenty years.

We review our long-lived assets for impairment whenever there is evidence that the carrying value of such assets may not be recoverable. Any impairment recognized is permanent and may not be restored. 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. Cash flows are developed based on estimated future production, and prices are then discounted using a market based rate of return consistent with that used by us in evaluating cash flows for other assets of a similar nature.

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.

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 have started the process of reviewing our lease agreements in light of the new guidance. Although we are in the early stages of our ASC 842 implementation project, we anticipate that this new lease guidance will cause significant changes to the way leases are recorded, presented and disclosed in our consolidated financial statements.

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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. The comparative information has not been restated and continues to be reported under the 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. We expect the impact of the adoption of the new standard 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.

For our crude oil marketing segment, most of our crude oil purchase and sale contracts qualify and are designated as non-trading activities, and we consider these contracts as normal purchases and sales activity. For normal purchases and sales, our customers are invoiced monthly based upon contractually agreed upon terms with revenue recognized in the month in which the physical product is delivered to the customer, generally upon delivery of the product to the customer. Revenue is recognized based on the transaction price and the quantity delivered.

The majority of our crude oil sales contracts have multiple distinct performance obligations as the promise to transfer the individual goods (e.g., barrels of crude oil) is separately identifiable from the other goods promised within the contracts. Our performance obligations are satisfied at a point in time. For normal sales arrangements, revenue is recognized in the month in which control of the physical product is transferred to the customer, generally upon delivery of the product to the customer.

For our transportation segment, each sales order associated with our master transportation agreements was 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 used significant judgment when assessing our contracts for impact upon adoption. For example, our 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 significant judgment. 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

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


•	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 sheet at the end of each reporting period.

Revenue Disaggregation

The following table disaggregates our revenue by segment and by major source for the three months ended March 31, 2018 (in thousands):



	Reporting Segments
	Marketing		Transportation		Total

Revenues from contracts with customers	$	360,085	$	13,618	$	373,703
Other ⁽¹⁾	13,553		—		13,553
Total revenues	$	373,638	$	13,618	$	387,256

Timing of revenue recognition:
Goods transferred at a point in time	$	360,085	$	—	$	360,085
Services transferred over time	—		13,618		13,618
Total revenues from contracts with customers	$	360,085	$	13,618	$	373,703

_______________


(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 trading activity 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.

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED 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
	March 31,
	2018		2017

Revenue gross-up	$	45,691	$	57,565

Note 4. Prepayments and Other Current Assets

The components of prepayments and other current assets were as follows at the dates indicated (in thousands):



	March 31,		December 31,
	2018		2017

Insurance premiums	$	414	$	425
Rents, licenses and other	697		839
Total	$	1,111	$	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	March 31,			December 31,
	in Years	2018			2017

Tractors and trailers ⁽¹⁾	5 – 6	$	86,492		$	88,065
Field equipment	2 – 5	18,827			18,490
Buildings	5 – 39	15,728			15,727
Office equipment	1 – 5	1,831			1,929
Land		1,790			1,790
Construction in progress		761			275
Total		125,429			126,276
Less accumulated depreciation		(97,685		)	(96,914		)
Property and equipment, net		$	27,744		$	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 $1.8 million and $1.8 million at March 31, 2018 and December 31, 2017 , respectively. Accumulated amortization associated with assets held under capital leases were $0.2 million and $0.1 million at March 31, 2018 and December 31, 2017 , respectively (see Note 11 for further information).

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Components of depreciation, depletion and amortization expense were as follows for the periods indicated (in thousands):



	Three Months Ended
	March 31,
	2018		2017
Depreciation, depletion and amortization, excluding amounts
under capital leases	$	2,322	$	3,969
Amortization of property and equipment under capital leases	90		—
Total depreciation, depletion and amortization	$	2,412	$	3,969

Note 6. Cash Deposits and Other Assets

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



	March 31,		December 31,
	2018		2017

Amounts associated with liability insurance program:
Insurance collateral deposits	$	3,517	$	3,767
Excess loss fund	1,959		2,284
Accumulated interest income	627		814
Other amounts:
State collateral deposits	53		57
Materials and supplies	331		273
Other	36		37
Total	$	6,523	$	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.

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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.

Information concerning our various business activities was as follows for the periods indicated (in thousands):



	Reporting Segments
	Marketing		Transportation			Oil and Gas			Total

Three Months Ended March 31, 2018
Revenues	$	373,638	$	13,618		$	—		$	387,256
Segment operating (losses) earnings ⁽¹⁾	2,958		402			—			3,360
Depreciation, depletion and amortization	1,497		915			—			2,412
Property and equipment additions	793		73			—			866

Three Months Ended March 31, 2017
Revenues	$	288,615	$	13,455		$	1,017		$	303,087
Segment operating (losses) earnings ⁽¹⁾	1,393		(298		)	(42		)	1,053
Depreciation, depletion and amortization	2,069		1,591			309			3,969
Property and equipment additions	82		102			822			1,006

_______________


(1)	Our marketing segment’s operating earnings included inventory liquidation gains of $0.6 million for the three months ended March 31, 2018, and inventory valuation losses of $0.7 million for the three months ended March 31, 2017.

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
	March 31,
	2018			2017

Segment operating earnings	$	3,360		$	1,053
General and administrative	(2,283		)	(2,637		)
Operating earnings (losses)	1,077			(1,584		)
Interest income	387			159
Interest expense	(19		)	(1		)
(Losses) earnings before income taxes	$	1,445		$	(1,426	)

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Identifiable assets by industry segment were as follows at the dates indicated (in thousands):



	March 31,		December 31,
	2018		2017

Reporting segment:
Marketing	$	135,759	$	134,745
Transportation	29,422		29,069
Oil and Gas ⁽¹⁾	425		425
Cash and other assets	118,902		118,465
Total assets	$	284,508	$	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, investments 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 such 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.

Activities with affiliates were as follows for the periods indicated (in thousands):



	Three Months Ended
	March 31,
	2018		2017

Affiliate billings to us	$	15	$	12
Billings to affiliates	2		1
Rentals paid to affiliate	122		167
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.

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 March 31, 2018 , we had in place 20 commodity purchase and sale contracts, of which two 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:


•	322 barrels per day of crude oil during April 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 through September 2018;


•	258 barrels per day of crude oil during October through December 2018; and


•	322 barrels per day of crude oil during January 2019 through March 2019.

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):



	March 31, 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	$	312	$	—	$	—	$	—
Liability derivatives:
Fair value forward hydrocarbon commodity
contracts at gross valuation	—		—		289		—
Less counterparty offsets	—		—		—		—
As reported fair value contracts	$	312	$	—	$	289	$	—

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 through May 2018;


•	258 barrels per day of crude oil during June 2018;

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


•	646 barrels per day of crude oil during July 2018;


•	322 barrels per day of crude oil during August through September 2018; and


•	258 barrels per day of crude oil during October through December 2018.



	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	$	—

We only enter into commodity contracts with creditworthy counterparties and evaluate our exposure to significant counterparties on an ongoing basis. At March 31, 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
	March 31,
	2018		2017

Revenues – marketing	$	1	$	420

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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):



	March 31, 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	$	—	$	312		$	—	$	—	$	312
Current liabilities	—		(289		)	—		—		(289		)
Net value	$	—	$	23		$	—	$	—	$	23



	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

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 March 31, 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.

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 10. Supplemental Cash Flow Information

Supplemental cash flows and non-cash transactions were as follows for the periods indicated (in thousands):



	Three Months Ended
	March 31,
	2018			2017

Cash paid for interest	$	19		$	—
Cash paid for federal and state taxes	52			14

Non-cash transactions:
Change in accounts payable related to property and equipment additions	(39		)	836

Note 11. Commitments and Contingencies

Capital Lease Obligations

We have 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 March 31, 2018 for the next five years, and in total thereafter (in thousands):



Remainder of 2018	$	299
2019	398
2020	398
2021	398
2022	255
Thereafter	—
Total minimum lease payments	1,748
Less: Amount representing interest	(142		)
Present value of capital lease obligations	1,606
Less current portion of capital lease obligations	(341		)
Total long-term capital lease obligations	$	1,265

Operating Lease Obligations

We lease certain property and equipment under noncancellable 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.

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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
	March 31,
	2018		2017

Rental expense	$	2,587	$	3,228

At March 31, 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	$	2,897
2019	2,016
2020	1,623
2021	1,513
2022	1,481
Thereafter	2,923
Total operating lease payments	$	12,453

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):



	March 31,		December 31,
	2018		2017

Pre-funded premiums for losses incurred but not reported	$	732	$	988
Accrued automobile and workers’ compensation claims	867		450

Table of Contents

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 $4.5 million . Medical accrual amounts were as follows at the dates indicated (in thousands):



	March 31,		December 31,
	2018		2017

Accrued medical claims	$	1,353	$	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.

Table of Contents

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.

Table of Contents

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
	March 31,
	2018		2017		Change ⁽¹⁾

Revenues	$	373,638	$	288,615	29	%
Operating earnings	2,958		1,393		112	%
Depreciation and amortization	1,497		2,069		(28	%)
Driver commissions	3,055		3,062		—	%
Insurance	1,289		1,239		4	%
Fuel	1,515		1,354		12	%

_________________________________


(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
	March 31,
	2018		2017
Field level purchase volumes – per day ⁽¹⁾
Crude oil – barrels	65,194		66,374

Average purchase price
Crude oil – per barrel	$	64.01	$	49.02

_________________________________


(1)	Reflects the volume purchased from third parties at the field level of operations.

Crude oil marketing revenues increased by $85.0 million during the three months ended March 31, 2018 as compared to the three months ended March 31, 2017, primarily as a result of an increase in the market price of crude oil, which increased revenues by approximately $91.8 million, partially offset by lower crude oil volumes, which decreased revenues by approximately $6.8 million. The average crude oil price received was $49.02 for the three months ended March 31, 2017, which increased to $64.01 for the three months ended March 31, 2018 .

Our crude oil marketing operating earnings for the three months ended March 31, 2018 increased by $1.6 million as compared to the same period in 2017, primarily as a result of an increase in the market price of crude oil. Operating earnings were also impacted by inventory valuation changes (as shown in the table below).

Driver commissions during the three months ended March 31, 2018 were consistent with the same period in 2017, with a slight decrease in crude oil marketing volumes in the 2018 period. Insurance costs increased by $0.1 million during the three months ended March 31, 2018 as compared to the same period in 2017, primarily as a result of increased mileage during the 2018 period as compared to the 2017 period, partially offset by favorable driver safety performance during the 2018 period. Fuel costs increased by $0.2 million during the three months ended March 31, 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 March 31, 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.

Table of Contents

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.

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
	March 31,
	2018			2017

As reported segment operating earnings ⁽¹⁾	$	2,958		$	1,393
Add (subtract):
Inventory liquidation gains	(552		)	—
Inventory valuation losses	—			658
Derivative valuation (gains) losses	(1		)	(420		)
Field level operating earnings ⁽²⁾	$	2,405		$	1,631

________________________________


(1)	Segment operating earnings included inventory liquidation gains of $0.6 million for the three months ended March 31, 2018 , and inventory valuation losses of $0.7 million for the three months ended March 31, 2017.


(2)	The use of field level operating earnings is (a) unique to us, (b) not a substitute for a GAAP measure and (c) 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 months ended March 31, 2018 as compared to the same period in 2017 due to an increase in the market price of crude oil, which increased revenues, and the effects of lower barge costs, which reduced operating expenses.

We held crude oil inventory at a weighted average composite price as follows at the dates indicated (in barrels):



	March 31, 2018			December 31, 2017
		Average			Average
	Barrels	Price		Barrels	Price

Crude oil inventory	296,808	$	64.91	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.

Table of Contents

Transportation

Our transportation segment revenues, operating earnings (losses) and selected costs were as follows for the periods indicated (in thousands):



	Three Months Ended
	March 31,
	2018		2017			Change ⁽¹⁾

Revenues	$	13,618	$	13,455		1	%
Operating earnings (losses)	$	402	$	(298	)	(235	%)
Depreciation and amortization	$	915	$	1,591		(42	%)
Driver commissions	$	2,880	$	2,836		2	%
Insurance	$	1,402	$	1,381		2	%
Fuel	$	1,876	$	1,632		15	%
Maintenance expense	$	1,527	$	1,638		(7	%)
Mileage (000s)	5,070		5,618			(10	%)

________________________________


(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
	March 31,
	2018			2017

Total transportation revenue	$	13,618		$	13,455
Diesel fuel cost	(1,876		)	(1,632		)
Revenues, net of fuel cost ⁽¹⁾	$	11,742		$	11,823

_________________________________


(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 $0.2 million during the three months ended March 31, 2018 , primarily as a result of a new transportation agreement entered into in January 2018 and higher transportation rates in the 2018 period. Revenues, net of fuel cost, decreased by $0.1 million during the three months ended March 31, 2018 , primarily as a result of an increase in the price of diesel during the 2018 period, partially offset by increased activity in our transportation segment. Transportation activity began to increase during late 2017, and we continue to pursue our strategy of streamlining operations and diversifying offerings in our transportation segment. This increase in services resulted in an increase in variable expenses related to transportation activities. 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. Depreciation and amortization expense decreased by $0.7 million during the three months ended March 31, 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.

Table of Contents

Oil and Gas

Our upstream crude oil and natural gas exploration and production segment revenues and operating earnings (losses) 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 three months ended March 31, 2017 were for the period in which AREC was consolidated.

Our upstream crude oil and natural gas exploration and production segment revenues, operating losses and depreciation and depletion expense were as follows for the period indicated (in thousands):



	Three Months Ended
	March 31,
	2017

Revenues	$	1,017
Operating losses	(42		)
Depreciation and depletion	309

Volume and price information were as follows for the period indicated (volumes in thousands):



	Three Months Ended
	March 31,
	2017
Crude oil
Volume – barrels	8,474
Average price per barrel	$	48.78

Natural gas
Volume – Mcf	140,707
Average price per Mcf	$	2.99

Natural gas liquids
Volume – barrels	7,293
Average price per barrel	$	25.00

General and Administrative Expense

General and administrative expense decreased by $0.4 million during the three months ended March 31, 2018 as compared to the same period in 2017 primarily due to the deconsolidation of AREC in April 2017 and lower personnel costs in the 2018 period as a result of an early retirement program implemented in August 2017.

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 months ended March 31, 2018 as compared to the same period in 2017.

Table of Contents

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 2018, we plan to leverage our investment in our transportation segment’s Houston terminal with the continued efforts to diversify service offerings and grow in new or existing areas with our crude oil marketing segment.

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 $0.4 million in 2018 when the bankruptcy case is dismissed.

At March 31, 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):



	March 31,		December 31,
	2018		2017

Cash and cash equivalents	$	111,536	$	109,393
Working capital	117,882		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 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 March 31, 2018 and December 31, 2017 , we had $0.4 million and $2.2 million , respectively, outstanding under this facility.

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 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.

Table of Contents

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.

Table of Contents

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):



	Three Months Ended
	March 31,
	2018			2017

Cash provided by (used in):
Operating activities	$	3,285		$	12,150
Investing activities	(131		)	(491		)
Financing activities	(1,011		)	(928		)

Operating activities . Net cash flows provided by operating activities for the three months ended March 31, 2018 decreased by $8.9 million when compared to the same period in 2017. This decrease was primarily due to an increase in operating expenses and the timing of collections of accounts receivable and payments of accounts payable, partially offset by increased revenues.

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):



	March 31,		December 31,
	2018		2017

Early payments received	$	19,699	$	20,078
Early payments to suppliers	4,825		6,100

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 first quarter of 2018, we elected to make several early payments in our crude oil marketing operations. Our cash balance increased by approximately $2.1 million as of March 31, 2018 relative to the year ended December 31, 2017 primarily as a result of the timing of the prepayments made and received during each period.

Investing activities . Net cash flows used in investing activities for the three months ended March 31, 2018 decreased by $0.4 million when compared to the same period in 2017. The decrease in net cash flows used in investing activities during the 2018 period was primarily due to a $0.1 million increase in cash proceeds from the sales of assets, a $0.1 million decrease in capital spending for property and equipment (see following table) and a $0.1 million increase in insurance and state collateral refunds.

Table of Contents

Capital spending was as follows for the periods indicated (in thousands):



	Three Months Ended
	March 31,
	2018		2017

Crude oil marketing	$	793	$	82
Truck transportation	73		102
Oil and natural gas exploration	—		822
Capital spending	$	866	$	1,006

Financing activities . Cash used in financing activities for the three months ended March 31, 2018 increased by $0.1 million when compared to the same period in 2017. During each of the three months ended March 31, 2018 and 2017, we paid a quarterly dividend of $0.22 per common share, or $0.9 million . During the 2018 period, we paid $0.1 million of principal repayments on capital lease obligations that we entered into in 2017 for certain of our tractors in our crude oil marketing segment, with principal contractual commitments to be paid over a period of five years.

Other Items

Contractual Obligations

The following table summarizes our significant contractual obligations at March 31, 2018 (in thousands):



			Payments due by period
	Total		Less than 1 year		1-3 years		3-5 years		More than 5 years

Capital lease obligations ⁽¹⁾	$	1,748	$	299	$	796	$	653	$	—
Operating lease obligations ⁽²⁾	12,453		2,897		3,639		2,994		2,923
Total contractual obligations	$	14,201	$	3,196	$	4,435	$	3,647	$	2,923

______________


(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.

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
	March 31,
	2018		2017

Rental expense	$	2,587	$	3,228

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.

Table of Contents

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.

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 March 31, 2018 , that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Table of Contents

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

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 our 2017 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.

Table of Contents

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	Bylaws of Adams Resources & Energy, Inc., as amended (incorporated by reference to Exhibit 3(b) to Form 10-K for the year ended December 31, 2012).
10.1+*	Adams Resources & Energy, Inc. 2018 Long-Term Incentive Plan, effective as of May 8, 2018.
10.2*	Seventh Amendment to Credit and Security Agreement dated as of March 19, 2018 between GulfMark Energy, Inc. and Wells Fargo Bank, National Association.
31.1*	Sarbanes-Oxley Section 302 certification of Executive Chairman pursuant to Exchange Act Rules 13a-14(a) and 15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*	Sarbanes-Oxley Section 302 certification of Chief Financial Officer pursuant to Exchange Act Rules 13a-14(a) and 15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1*	Sarbanes-Oxley Section 906 certification of Executive Chairman pursuant to 18. U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2*	Sarbanes-Oxley Section 906 certification of Chief Financial Officer pursuant to 18. U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.CAL*	XBRL Calculation Linkbase Document
101.DEF*	XBRL Definition Linkbase Document
101.INS*	XBRL Instance 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.

Table of Contents

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: May 9, 2018	By:	/s/ Townes G. Pressler
		Townes G. Pressler
		Executive Chairman
		(Principal Executive Officer)

	By:	/s/ Sharon C. Davis
		Sharon C. Davis
		Interim Chief Financial Officer
		(Principal Financial Officer and Principal
		Accounting Officer)

TABLE OF CONTENTS

Part I. Financial Informationprint Item 1. Financial Statementsprint Note 1. Organization and Basis Of Presentationprint Note 2. General Accounting and Disclosure Mattersprint Note 3. Revenue Recognitionprint Note 4. Prepayments and Other Current Assetsprint Note 5. Property and Equipmentprint Note 6. Cash Deposits and Other Assetsprint Note 7. Segment Reportingprint Note 8. Transactions with Affiliatesprint Note 9. Derivative Instruments and Fair Value Measurementsprint Note 10. Supplemental Cash Flow Informationprint Note 11. Commitments and Contingenciesprint Item 2. Management S Discussion and Analysis Of Financial Condition and Results Of Operationsprint Item 3. Quantitative and Qualitative Disclosures About Market Riskprint Item 4. Disclosure Controls and Proceduresprint Part II. Other Informationprint Item 1. Legal Proceedingsprint Item 1A. Risk Factorsprint Item 2. Unregistered Sales Of Equity Securities and Use Of Proceedsprint Item 3. Defaults Upon Senior Securitiesprint Item 4. Mine Safety Disclosuresprint Item 5. Other Informationprint Item 6. Exhibitsprint

Exhibits

3.2 Bylaws of Adams Resources & Energy, Inc., as amended (incorporated by reference to Exhibit 3(b) to Form 10-K for the year ended December 31, 2012). 10.1+* Adams Resources & Energy, Inc. 2018 Long-Term Incentive Plan, effective as of May 8, 2018. 10.2* Seventh Amendment to Credit and Security Agreement dated as of March 19, 2018 between GulfMark Energy, Inc. and Wells Fargo Bank, National Association. 31.1* Sarbanes-Oxley Section 302 certification of Executive Chairman pursuant to Exchange Act Rules 13a-14(a) and 15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. 31.2* Sarbanes-Oxley Section 302 certification of Chief Financial Officer pursuant to Exchange Act Rules 13a-14(a) and 15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. 32.1* Sarbanes-Oxley Section 906 certification of Executive Chairman pursuant to 18. U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. 32.2* Sarbanes-Oxley Section 906 certification of Chief Financial Officer pursuant to 18. U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

DIRECTORS	AGE	BIO	OTHER DIRECTOR MEMBERSHIPS
Thomas E Whiddon	72	Qualifications Mr. Whiddon’s general management, information technology and logistics expertise, strong financial acumen, and experience with retail end markets are beneficial to the Board. The Board has determined that Mr. Whiddon is an audit committee financial expert within the meaning of the rules of the SEC. His previous service on the boards and audit committees of two other public companies provides him with valuable regulatory and corporate governance experience. Committees • Audit (Financial Expert) • Corporate Governance and Nominating • Executive Compensation
Theresa J Drew	67	Qualifications Ms. Drew has forty years of accounting and consulting experience with Deloitte, which has provided her with in-depth financial, auditing, and accounting experience related to various businesses and industries, as well as senior leadership experience. Her service on a board and audit committee of another public company provides her with additional regulatory and corporate governance experience. The Board has determined that Ms. Drew is an audit committee financial expert within the meaning of the rules of the Securities and Exchange Commission (the “SEC”). Committees • Audit (Chair and Financial Expert) • Financial Policy
Steven L Boyd	67	Qualifications Mr. Boyd brings extensive experience as an executive leader. His knowledge of consumer products, customer management, product distribution, acquisition integration, community relations, and marketing and sales operations add valuable insight to the board and global business. Committees • Audit • Employee and Public Responsibility
Scott A Clark	59	Qualifications Mr. Clark’s extensive executive leadership experience at Michelin Group with responsibilities for the company’s largest global business segments and geographic markets provides valuable knowledge of European markets which are important to Sonoco’s continued operational and future growth, as well as valuable diverse consumer goods experience. Committees • Audit • Executive Compensation
Robert R Hill Jr	58	ROBERT R. HILL JR. Lead Independent Director since 2022
Richard G Kyle	59	Richard G. Kyle Former President and Chief Executive Officer, The Timken Company	TIMKEN CO
Philippe Guillemot	65	Qualifications Mr. Guillemot possesses a wealth of executive leadership experience. His experience as an executive officer and director of other public manufacturing companies provides him with valuable corporate governance, financial, and regulatory knowledge. Mr. Guillemot brings global experience and leadership, including with respect to operations in Europe, where Sonoco has a significant footprint, in particular following our 2024 acquisition of Eviosys. Committees • Employee and Public Responsibility • Financial Policy
Pamela L Davies	68	Qualifications Dr. Davies brings to the board financial and strategic planning expertise, broad leadership ability, global perspective, and a strong business academic viewpoint derived from her service as president of a university and former dean of its business school. Her past experience on the boards of other public companies also provides her with valuable regulatory experience and an understanding of corporate governance issues. Committees • Corporate Governance and Nominating • Employee and Public Responsibility (Chair) • Executive Compensation
John R Haley	63	Mr. Haley is the brother-in-law of R. Howard Coker, Sonoco’s President and Chief Executive Officer. Qualifications Mr. Haley has extensive executive leadership experience in the manufacturing and automation sectors. His related experience in corporate finance and his experience in sales and marketing provide valuable insights for the Board. He currently serves as the Chairman. Committees • Executive (Chair)
Howard Coker	62	Mr. Coker is the brother-in-law of J.R. Haley, Chairman of the Board of Directors. Qualifications Mr. Coker’s strong operating acumen, extensive experience, deep connection within the organization, and his leadership style and vision for the Company have been proven over his 40 years of service. He has played a significant role in the development of the global Industrial and Consumer businesses and has built an outstanding track record of growth and improved business operations. Committees • Executive


Name and Principal Position	Year		Salary ($)			Bonus ($)		Stock Awards ($)			Non Equity Incentive Plan Compensation ($)			Change in Pension Value and Nonqualified Deferred Compensation Earnings ($)		All Other Compensation ($)			Total ($)
R. Howard Coker President and Chief Executive Officer		2024		$	1,233,011		0		$	6,829,915		$	1,645,511		0		$	399,365		$	10,107,802
		2023			1,192,388		0			6,876,983			0		0			469,222			8,538,593
		2022			1,098,385		0			6,205,527			1,977,093		0			513,043			9,794,049
Robert R. Dillard Former Chief Financial Officer		2024			709,358		0			2,016,447			643,737		0			149,097			3,518,639
		2023			654,959		0			1,529,341			0		0			180,812			2,365,113
		2022			535,539		0			1,019,828			635,446		0			175,267			2,366,080
Rodger D. Fuller Chief Operating Officer		2024			775,359		0			2,018,812			724,327		0			205,997			3,724,494
		2023			749,814		0			2,041,641			0		0			242,089			3,033,544
		2022			720,980		0			1,885,304			939,681		0			281,088			3,827,053
John M. Florence, Jr. General Counsel, Secretary, & Vice President / General Manager–Paper Packaging, North America		2024			577,346		0			1,014,021			431,477		0			130,151			2,152,996
		2023			558,330		0			1,027,632			0		0			151,136			1,737,098
		2022			536,864		0			1,023,237			563,707		0			176,167			2,299,975
James A. Harrell, III President, Global Industrial Paper Packaging Division		2024			624,243		0			790,171			499,849		0			147,699			2,061,962
		2023			603,682		0			804,175			0		0			169,715			1,577,572
		2022			567,579		0			773,304			595,958		0			185,545			2,122,386

Supplier name	Ticker
ConocoPhillips	COP
Chevron Corporation	CVX
EOG Resources, Inc.	EOG
Freedom Holding Corp.	FRHC
Hess Corporation	HES
ONEOK, Inc.	OKE
Exxon Mobil Corporation	XOM

Owner	Position	Direct Shares	Indirect Shares
Coker R. Howard	-	482,365	17,874
HILL ROBERT R JR	-	29,540	0
Wood Adam	-	28,273	0
Cairns Sean	-	15,668	0
Grissett Russell K	-	11,988	958
Haynes Ernest D III	-	7,796	35
Florence John M	-	7,052	23
Cairns Sean	-	5,379	0
Cheatham Jerry A	-	3,683	2,259
Haynes Ernest D III	-	81	51

AE 10-Q Quarter ended March 31, 2018

Exhibits