SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D. C. 20549

FORM 10‑Q

☒	Quarterly report pursuant to Section 13 or 15 (d) of the Securities Exchange Act of 1934

For the quarterly period ended March 31, 2017

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 office & Zip Code)

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

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

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 ☒ 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 the definitions of ‟large accelerated filer”, ‟accelerated filer” and ‟smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer ☐	Accelerated filer ☒
Non-accelerated filer ☐	Smaller Reporting Company ☐
(Do not check if a smaller reporting company)
Emerging growth company ☐

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. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES ☐ NO ☒

A total of 4,217,596 shares of Common Stock were outstanding at May 1, 2017.

PART 1 – FINANCIAL INFORMATION

Item 1. Financial Statements

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

	Three Months Ended
	March 31,
	2017			2016
REVENUES:
Marketing	$	288,615		$	236,394
Transportation		13,455			13,347
Oil and natural gas		1,017			790
		303,087			250,531
COSTS AND EXPENSES:
Marketing		285,153			229,057
Transportation		12,162			11,189
Oil and natural gas operations		750			631
General and administrative		2,637			2,200
Depreciation, depletion and amortization		3,969			5,115
		304,671			248,192

Operating (loss) earnings		(1,584	)		2,339

Other income (expense):
Interest income		159			103
Interest expense		(1	)		-

(Loss) earnings before income taxes and equity investments		(1,426	)		2,442

Income tax benefit (provision)		566			(888	)

(Loss) earnings before equity investments		(860	)		1,554
(Loss) from equity investments, net of tax benefit of zero
and $67, respectively		-			(124	)
Net (loss) earnings	$	(860	)	$	1,430

(LOSS) EARNINGS PER SHARE:
Basic and diluted net (loss) earnings per common share	$	(.20	)	$	.34


DIVIDENDS PER COMMON SHARE	$	.22		$	.22

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

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

	March 31,			December 31,
	2017			2016
ASSETS
Current assets:
Cash and cash equivalents	$	98,073		$	87,342
Accounts receivable, net of allowance for doubtful
accounts of $233 and $225, respectively		89,122			87,162
Inventory		20,627			13,070
Fair value contracts		468			112
Income tax receivable		3,471			2,735
Prepayments		1,353			2,097

Total current assets		213,114			192,518

Property and Equipment
Marketing		56,511			56,907
Transportation		70,767			70,849
Oil and gas (successful efforts method)		64,063			62,784
Other		107			108
		191,448			190,648

Less – Accumulated depreciation, depletion and amortization		(147,639	)		(144,323	)
		43,809			46,325
Other Assets:
Investments		2,500			2,500
Cash deposits and other		4,740			5,529
	$	264,163		$	246,872

LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities:
Accounts payable	$	97,978		$	79,897
Accounts payable – related party		56			53
Fair value contracts		-			64
Accrued and other liabilities		7,303			6,060

Total current liabilities		105,337			86,074

Other Liabilities:
Asset retirement obligations		2,090			2,329
Deferred taxes and other liabilities		7,212			7,157
		114,639			95,560
Commitments and Contingencies (Note 5)

Shareholders’ Equity:
Preferred stock - $1.00 par value, 960,000 shares
authorized, none outstanding		-			-
Common stock - $.10 par value, 7,500,000 shares
authorized, 4,217,596 shares outstanding		422			422
Contributed capital		11,693			11,693
Retained earnings		137,409			139,197
Total shareholders’ equity		149,524			151,312
	$	264,163		$	246,872

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

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

	Three Months Ended
	March 31,
	2017			2016
CASH PROVIDED BY OPERATIONS:
Net (loss) earnings	$	(860	)	$	1,430
Adjustments to reconcile net earnings to net cash
from operating activities -
Depreciation, depletion and amortization		3,969			5,115
Property sales loss (gains)		7			(120	)
Impairment of oil and natural gas properties		3			29
Deferred income taxes		60			(1,352	)
Net change in fair value contracts		(420	)		158
Equity investment losses		-			191
(Increase) in accounts receivable		(1,968	)		(1,224	)
(Increase) in inventories		(7,557	)		(5,707	)
Decrease (increase) in income tax receivable		(736	)		1,958
Decrease in prepayments		744			338
Increase (decrease) in accounts payable		17,746			(3,614	)
Increase in accrued liabilities		1,084			393
Other changes, net		78			47

Net cash provided by (used in) operating activities		12,150			(2,358	)

INVESTING ACTIVITIES:
Property and equipment additions		(1,006	)		(4,210	)
Proceeds from property sales		39			920
Investments		-			(2,200	)
Insurance and state collateral (deposits) refunds		476			(2	)

Net cash used in investing activities		(491	)		(5,492	)

FINANCING ACTIVITIES
Dividend payments		(928	)		(928	)

Net cash used in financing activities		(928	)		(928	)

Increase (decrease) in cash and cash equivalents		10,731			(8,778	)

Cash and cash equivalents at beginning of period		87,342			91,877

Cash and cash equivalents at end of period	$	98,073		$	83,099

The accompanying notes are an integral part of these financial statements

ADAMS RESOURCES & ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED

CONSOLIDATED FINANCIAL STATEMENTS

Note 1 - Basis of Presentation

The accompanying unaudited condensed consolidated financial statements, in the opinion of Adams Resources & Energy, Inc., a Delaware corporation, and its wholly owned subsidiaries (collectively, the “Company”) management, include all adjustments (consisting of normal recurring accruals) necessary for the fair presentation of its financial position at March 31, 2017, its results of operations for the three months ended March 31, 2017 and 2016 and its cash flows for the three months ended March 31, 2017 and 2016. Certain information and note disclosures normally included in annual financial statements prepared in accordance with generally accepted accounting principles (‟GAAP”) have been condensed or omitted pursuant to Securities and Exchange Commission rules and regulations.

Although the Company believes the disclosures made are adequate to make the information presented not misleading, it is suggested that these unaudited condensed consolidated financial statements be read in conjunction with the financial statements, and the notes thereto, included in the Company's latest Annual Report on Form 10-K. The interim statement of operations is not necessarily indicative of results to be expected for a full year.

Note 2 - Summary of Significant Accounting Policies

Nature of Operations and Principles of Consolidation

The Company is engaged in the business of crude oil marketing, tank truck transportation of liquid chemicals and dry bulk, and oil and gas exploration and production. The accompanying unaudited condensed consolidated financial statements include the accounts of the Company after elimination of all intercompany accounts and transactions.

Cash and Cash Equivalents

Cash and cash equivalents include any Treasury bill, commercial paper, money market fund or federal funds with maturity of 90 days or less. Cash and cash equivalents are maintained with major financial institutions and such deposits may exceed the amount of federally backed insurance provided. While the Company regularly monitors the financial stability of such institutions, cash and cash equivalents ultimately remain at risk subject to the financial viability of such institutions.

Inventory

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

Prepayments

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

	March 31,		December 31,
	2017		2016

Insurance premiums	$	767	$	1,403
Rents, license and other		586		694
	$	1,353	$	2,097

Property and Equipment

Expenditures for major renewals and betterments are capitalized, and expenditures for maintenance and repairs are expensed as incurred. Interest costs incurred in connection with major capital expenditures are capitalized and amortized over the lives of the related assets. When properties are retired or sold, the related cost and accumulated depreciation, depletion and amortization is removed from the accounts and any gain or loss is reflected in earnings.

Oil and gas exploration and development expenditures are accounted for in accordance with the successful efforts method of accounting. Direct costs of acquiring developed or undeveloped leasehold acreage, including lease bonus, brokerage and other fees, are capitalized. Exploratory drilling costs are initially capitalized until the properties are evaluated and determined to be either productive or nonproductive. Such evaluations are made on a quarterly basis. If an exploratory well is determined to be nonproductive, the costs of drilling the well are charged to expense. Costs incurred to drill and complete development wells, including dry holes, are capitalized. As of March 31, 2017, the Company had no unevaluated or suspended exploratory drilling costs.

Depreciation, depletion and amortization of the cost of proved oil and gas properties is calculated using the unit-of-production method. The reserve base or denominator used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. For lease and well equipment, development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. The numerator for such calculations is actual production volumes for the period. All other property and equipment is depreciated using the straight-line method over the estimated average useful lives of three to twenty years.

The Company reviews its long-lived assets for impairment whenever there is evidence that the carrying value of such assets may not be recoverable. Any impairment recognized is permanent and may not be restored. Producing oil and gas properties are reviewed on a field-by-field basis. Fields with carrying values in excess of their estimated undiscounted future net cash flows are deemed impaired. For properties requiring impairment, the fair value is estimated based on an internal discounted cash flow model. Cash flows are developed based on estimated future production and prices are then discounted using a market based rate of return consistent with that used by the Company in evaluating cash flows for other assets of a similar nature.

On a quarterly basis, management evaluates the carrying value of non-producing oil and gas leasehold properties and may deem them impaired based on remaining lease term, area drilling activity and the Company’s plans for the property. This fair value measure depends highly on management’s assessment of the likelihood of continued exploration efforts in a given area. Therefore, such data inputs are categorized as ‟unobservable” or ‟Level 3” inputs. (See ‟Fair Value Measurements” below). Importantly, this fair value measure only applies to the write-down of capitalized costs and will never result in an increase to reported earnings.

Impairment provisions are included in oil and gas segment operating losses and were as follows (in thousands):

	Three Months Ended
	March 31,
	2017		2016
Producing property impairments	$	-	$	1
Non-producing property impairments		3		28
Total	$	3	$	29

Since the Company is no longer the operator of its oil and gas property interests, it does not maintain the underlying detail acreage data and the Company is dependent on the operator when determining which specific acreage will ultimately be drilled. However, the capitalized cost detail on a property-by-property basis is reviewed by management, and deemed impaired if development is not anticipated prior to lease expiration. Onshore leasehold periods are normally three years and may contain renewal options.

Investments

In December 2015 the Company formed a new wholly owned subsidiary, Adams Resources Medical Management, Inc. (ARMM), and in January 2016 ARMM acquired a 30% member interest in Bencap LLC (Bencap) for a $2.2 million cash payment. Bencap provides medical insurance brokerage and medical claims auditing services to employers utilizing ERISA governed employee benefit plans. The Company has accounted for this investment under the equity method of accounting.

During the third quarter of 2016, the Company completed a review of its equity method investment in Bencap and determined there was an other than temporary impairment. Underlying this was the terms of the investment agreement where Bencap had the option to request borrowings up to $1.5 million (on or after December 5, 2016 but before October 31, 2018) that the Company must provide or forfeit its 30% member interest. During the third quarter of 2016, management of the Company determined that it was unlikely to provide additional funding due to Bencap’s lower than projected revenue growth and operating losses since investment inception. As a result, the Company recognized a net loss of $1.4 million from its investment in Bencap as of September 30, 2016. This loss included a pre-tax impairment charge of $1.7 million and pre-tax losses from the equity method investment of $0.5 million. In February 2017, Bencap requested additional funding of approximately $0.5 million and the Company declined the additional funding request and forfeited its 30% member interest in BenCap.

In April 2016 the Company, through its ARMM subsidiary, acquired an approximate 15% equity interest (less than 3% voting interest) in VestaCare, Inc., a California corporation (“VestaCare”), for a $2.5 million cash payment. VestaCare provides an array of software as a service (“SaaS”) electronic payment technologies to medical providers, payers and patients including VestaCare’s most recent product offering, VestaPay™. VestaPay™ allows medical care providers to structure fully automated and dynamically updating electronic payment plans for their patients. The Company has accounted for this investment under the cost method of accounting for investments. The Company does not currently have any plans to pursue additional medical-related investments.

The Company’s remaining investment in VestaCare, Inc. is considered a long-lived asset and will be reviewed for impairment whenever there is evidence that the carrying value of such asset may not be recoverable. These fair value measures depend highly on management’s assessment of the financial status of the underlying operation. Such data inputs are “unobservable” or “Level 3” inputs.

Cash Deposits and Other Assets

The Company has established certain deposits to support participation in its liability insurance program and remittance of state crude oil severance taxes and other state collateral deposits. Insurance collateral deposits are invested at the discretion of the Company’s insurance carrier and such investments primarily consist of intermediate term federal government bonds and bonds backed by federal agencies. This fair value measure relies on inputs from quoted prices for similar assets and is thus categorized as a ‟Level 2” valuation in the fair value hierarchy. Components of cash deposits and other assets are as follows (in thousands):

	March 31,		December 31,
	2017		2016
Insurance collateral deposits	$	4,222	$	5,032
State collateral deposits		141		143
Materials and supplies		377		354
	$	4,740	$	5,529

Revenue Recognition

Certain commodity purchase and sale contracts utilized by the Company’s marketing business qualify as derivative instruments with certain specifically identified contracts also designated as trading activity. From the time of contract origination, such trading activity contracts are marked-to-market and recorded on a net revenue basis in the accompanying financial statements.

Most crude oil purchase contracts and sale contracts qualify and are designated as non-trading activities and the Company considers such contracts as normal purchases and sales activity. For normal purchases and sales, the Company’s customers are invoiced monthly based upon contractually agreed upon terms with revenue recognized in the month in which the physical product is delivered to the customer. Such sales are recorded gross in the financial statements because the Company takes title, has risk of loss for the products, is the primary obligor for the purchase, establishes the sale price independently with a third party and maintains credit risk associated with the sale of the product.

Certain crude oil contracts may be with a single counterparty to provide for similar quantities of crude oil to be bought and sold at different locations. These contracts are entered into for a variety of reasons, including effecting the transportation of the commodity, to minimize credit exposure, and/or to meet the competitive demands of the customer. Such buy/sell arrangements are reflected on a net revenue basis in the accompanying unaudited condensed consolidated financial statements. Reporting such crude oil contracts on a gross revenue basis would increase the Company’s reported revenues as follows (in thousands):

	Three Months Ended
	March 31,
	2017		2016

Revenue gross-up	$	57,565	$	75,927

Transportation segment customers are invoiced, and the related revenue is recognized, as the service is provided. Oil and gas revenue from the Company’s interests in producing wells is recognized as title and physical possession of the oil and gas passes to the purchaser.

Sales of Long-lived assets

Gains and losses from the sale or disposal of long-lived assets that do not meet the criteria for presentation as a discontinued operation are presented in the accompanying financial statements as a component of operating earnings.

Concentration of Credit Risk

The Company’s largest customers consist of large multinational integrated oil companies and independent refiners of crude oil. In addition, the Company transacts business with independent oil producers, major chemical concerns, crude oil trading companies and a variety of commercial energy users. Within this group of customers the Company generally derives approximately 50 percent of its revenues from three to five crude oil refining concerns. While the Company has ongoing established relationships with certain domestic refiners of crude oil, alternative markets are readily available since the Company supplies less than one percent of U.S. domestic refiner demand. As a fungible commodity delivered to various supply points, the Company’s crude oil sales can be readily delivered to alternative end markets. Management believes that a loss of any of those customers where the Company currently derives more than 10 percent of its revenues would not have a material adverse effect on the Company’s operations.

Accounts receivable associated with crude oil activities comprise approximately 90 percent of the Company’s total receivables and industry practice requires payment for such sales to occur within 20 days of the end of the month following a transaction. The Company’s customer makeup, credit policies and the relatively short duration of receivables mitigate the uncertainty typically associated with receivables management.

Letter of Credit Facility

The Company maintains a Credit and Security Agreement with Wells Fargo Bank to provide up to a $60 million stand-by letter of credit facility used to support crude oil purchases within the marketing segment. This facility is collateralized by the eligible accounts receivable within the segment and outstanding amounts were as follows (in thousands):

	Three Months Ended
	March 31,
	2017		2016

Stand-by letters of credit	$	-	$	1,000

The issued stand-by letters of credit are cancelled as the underlying purchase obligations are satisfied by cash payment when due. The letter of credit facility places certain restrictions on Gulfmark Energy, Inc. the Company’s wholly owned subsidiary. Such restrictions include the maintenance of a combined 1.1 to 1.0 current ratio and the maintenance of positive net earnings excluding inventory valuation changes, as defined, among other restrictions. The Company is currently in compliance with all such financial covenants.

Statement of Cash Flows

There were no significant non-cash financing activities in any of the periods reported. Statements of cash flow disclosure items include the following (in thousands):

	Three Months Ended
	March 31,
	2017		2016

Federal and state tax paid	$	14	$	105

Capitalized amounts included in property and equipment that were not included in amounts reported for cash additions in the Statements of Cash Flows for the applicable report dates were as follows (in thousands):

	March 31,
	2017		2016

Property and equipment additions	$	836	$	350

Earnings Per Share

Earnings per share are based on the weighted average number of shares of common stock and potentially dilutive common stock shares outstanding during the period presented herein. The weighted average number of shares outstanding was 4,217,596 for 2017 and 2016. There were no potentially dilutive securities during those periods.

Share-Based Payments

During the periods presented herein, the Company had neither stock-based employee compensation plans nor any other share-based payment arrangements.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Examples of significant estimates used in the accompanying consolidated financial statements include oil and gas reserve volumes forming the foundation for calculating depreciation, depletion and amortization and for estimating cash flows when assessing impairment triggers and when estimating values associated with oil and gas properties. Other examples include revenue accruals, the provision for bad debts, insurance related accruals, income tax permanent and timing differences, contingencies and valuation of fair value contracts.

Income Taxes

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

Use of Derivative Instruments

The Company’s marketing segment is involved in the purchase and sale of crude oil. The Company seeks 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, such transactions are made pursuant to the terms of forward month commodity purchase and/or sale contracts. Some of these contracts meet the definition of a derivative instrument, and therefore, the Company accounts for such contracts at fair value, unless the normal purchase and sale exception is applicable. Such underlying contracts are standard for the industry and are the governing document for the Company’s crude oil marketing segment. None of the Company’s derivative instruments have been designated as hedging instruments. The accounting methodology utilized by the Company for its commodity contracts is further discussed below under the caption ‟Fair Value Measurements”.

The estimated fair value of forward month commodity contracts (derivatives) is reflected in the accompanying Unaudited Condensed Consolidated Balance Sheet as of March 31, 2017 as follows (in thousands):

	Balance Sheet Location and Amount
	Current			Other		Current			Other
	Assets			Assets		Liabilities			Liabilities
Asset Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation	$	750		$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-			-		282			-
Less Counterparty Offsets		(282	)		-		(282	)		-

As Reported Fair Value Contracts	$	468		$	-	$	-		$	-

As of March 31, 2017, four commodity purchase and sale contracts comprise the Company’s derivative valuations. These contracts encompass 145,000 barrels of crude oil during April 2017 through May 2017.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Balance Sheet as of December 31, 2016 as follows (in thousands):

	Balance Sheet Location and Amount
	Current			Other		Current			Other
	Assets			Assets		Liabilities			Liabilities
Asset Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation	$	378		$	-	$	-		$	-
Liability Derivatives
- Fair Value Forward Hydrocarbon Commodity
Contracts at Gross Valuation		-			-		330			-
Less Counterparty Offsets		(266	)		-		(266	)		-

As Reported Fair Value Contracts	$	112		$	-	$	64		$	-

As of December 31, 2016, two contracts comprised the Company’s derivative valuations. These contracts encompass approximately 65 barrels per day of diesel fuel during January through March 2017 and 145,000 barrels of crude oil during January 2017 through April 2017.

The Company only enters into commodity contracts with creditworthy counterparties and evaluates its exposure to significant counterparties on an ongoing basis. As of March 31, 2017 and December 31, 2016, the Company was not holding nor has it posted any collateral to support its forward month fair value derivative activity. The Company is not subject to any credit-risk related trigger events. The Company has no other financial investment arrangements that would serve to offset its derivative contracts.

Forward month commodity contracts (derivatives) are reflected in the accompanying Unaudited Condensed Consolidated Statement of Operations for the three months ended March 31, 2017 and 2016 as follows (in thousands):

	Earnings (Loss)
	Three Months Ended
	March 31,
	2017		2016
Revenues – Marketing	$	420	$	158

Fair Value Measurements

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

Fair value contracts consist of derivative financial instruments and are recorded as either an asset or liability measured at its fair value. Changes in fair value are recognized immediately in earnings unless the derivatives qualify for, and the Company elects, cash flow hedge accounting. The Company had no contracts designated for hedge accounting during any current reporting periods.

Fair value estimates are based on assumptions that market participants would use when pricing an asset or liability and the Company uses a fair value hierarchy of three levels that prioritizes the information used to develop those assumptions. Currently, for all items presented herein, the Company utilizes a market approach to valuing its contracts. On a contract by contract, forward month by forward month basis, the Company obtains observable market data for valuing its contracts. The fair value hierarchy gives the highest priority to quoted prices in active markets and the lowest priority to unobservable data. The fair value hierarchy is summarized as follows:

Level 1 – quoted prices in active markets for identical assets or liabilities that may be accessed at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. For Level 1 valuation of marketable securities, the Company utilizes market quotations provided by its primary financial institution and for the valuation of derivative financial instruments the Company utilizes the New York Mercantile Exchange (‟NYMEX”) for such valuations.

Level 2 – (a) quoted prices for similar assets or liabilities in active markets, (b) quoted prices for identical assets or liabilities but in markets that are not actively traded or in which little information is released to the public, (c) observable inputs other than quoted prices and (d) inputs derived from observable market data. Source data for Level 2 inputs include information provided by the NYMEX, published price data and indices, third party price survey data and broker provided forward price statistics.

Level 3 – unobservable market data inputs for assets or liabilities.

As of March 31, 2017, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets			Total
Derivatives
- Current assets	$	-	$	750		$	-	$	(282	)	$	468
- Current liabilities		-		(282	)		-		282			-
Net Value	$	-	$	468		$	-	$	-		$	468

As of December 31, 2016, the Company’s fair value assets and liabilities are summarized and categorized as follows (in thousands):

	Market Data Inputs
	Gross Level 1		Gross Level 2			Gross Level 3		Counterparty
	Quoted Prices		Observable			Unobservable		Offsets			Total
Derivatives
- Current assets	$	-	$	378		$	-	$	(266	)	$	112
- Current liabilities		-		(330	)		-		266			(64	)
Net Value	$	-	$	48		$	-	$	-		$	48

When determining fair value measurements, the Company makes credit valuation adjustments to reflect both its own nonperformance risk and its counterparty’s nonperformance risk. When adjusting the fair value of derivative contracts for the effect of nonperformance risk, the impact of netting and any applicable credit enhancements, considered. Credit valuation adjustments utilize Level 3 inputs, such as credit scores to evaluate the likelihood of default by the Company or its counterparties. As of March 31, 2017 and December 31, 2016, credit valuation adjustments were not significant to the overall valuation of the Company’s fair value contracts. As a result, applicable fair value assets and liabilities are included in their entirety in the fair value hierarchy.

Recent Accounting Pronouncements

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” which supersedes the revenue recognition requirements in “Revenue Recognition (Topic 605).” Topic 606 is based on the core principle that revenue is recognized to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for those goods or services. Topic 606 also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers, including significant judgments and changes in judgments and assets recognized from costs incurred to obtain or fulfill a contract.

Topic 606 is effective for fiscal years beginning after December 15, 2017, and interim periods within those years, with early adoption permitted in 2017; however we do not plan to adopt the standard early. Entities will have the option to apply the standard using a full retrospective or modified retrospective adoption method. The Company has not yet selected a transition method. The Company has a team in place to analyze the impact of Update 2014-09, and the related ASU's, across all revenue streams to evaluate the impact of the new standard on revenue contracts. This includes reviewing current accounting policies and practices to identify potential differences that would result from applying the requirements under the new standard. Our evaluation of the impact on our Consolidated Financial Statements and related disclosures is ongoing and not complete. The Company is continuing our review of contracts relative to the provisions of Topic 606.

In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842).” This standard requires, among other things, that lessees recognize the following for all leases (with the exception of short-term leases) at the commencement date: (1) a lease liability, which is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted basis; and (2) a right-of-use asset, which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term. Lessees and lessors must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The Company expects to adopt this standard in the first quarter of 2019 and is currently evaluating the impact of this standard on our Consolidated Financial Statements and related disclosures. In connection with our assessment work, The Company has a team in place to analyze the impact of ASU 2016-02 and is continuing a review of our contracts relative to the provisions of the lease standard.

In August 2016, the FASB issued ASU No. 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments.” This standard is intended to reduce existing diversity in practice in how certain transactions are presented on the statement of cash flows. The standard is effective for interim and annual reporting periods beginning after December 15, 2017, although early adoption is permitted. The guidance requires application using a retrospective transition method. The Company adopted ASU No. 2016-15 in the first quarter of 2017 and has determined the amendment does not have a material impact on our Consolidated Financial Statements and related disclosures.

Management believes the impact of other recently issued standards and updates, which are not yet effective, will not have a material impact on the Company’s consolidated financial position, results of operations, or cash flows upon adoption.

Note 3 – Segment Reporting

The Company’s three reporting segments are crude oil marketing, tank truck transportation of liquid chemicals and dry bulk, and oil and gas exploration and production. Information concerning the Company's various business activities is summarized as follows (in thousands):

- Three Month Comparison

			Segment			Depreciation		Property and
			Operating (Loss)			Depletion and		Equipment
	Revenues		Earnings			Amortization		Additions
Period Ended March 31, 2017
Marketing	$	288,615	$	1,393		$	2,069	$	82
Transportation		13,455		(298	)		1,591		102
Oil and gas		1,017		(42	)		309		822
	$	303,087	$	1,053		$	3,969	$	1,006
Period Ended March 31, 2016
Marketing	$	236,394	$	4,648		$	2,689	$	263
Transportation		13,347		173			1,985		3,817
Oil and gas		790		(282	)		441		130
	$	250,531	$	4,539		$	5,115	$	4,210

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

	Three Months Ended
	March 31,
	2017			2016
Segment operating earnings	$	1,053		$	4,539
- General and administrative		(2,637	)		(2,200	)
Operating (loss) earnings		(1,584	)		2,339
- Interest income		159			103
- Interest expense		(1	)		-
(Loss) Earnings before income tax	$	(1,426	)	$	2,442

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

	March 31,		December 31,
	2017		2016
Marketing	$	114,526	$	107,257
Transportation		32,231		32,120
Oil and gas		8,167		7,279
Other		109,239		100,216
	$	264,163	$	246,872

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

Note 4 - Transactions with Affiliates

The late Mr. K. S. Adams, Jr., former Chairman of the Board of the Company, and certain of his family partnerships and affiliates have participated as working interest owners with the Company’s wholly owned subsidiary, Adams Resources Exploration Corporation (‟AREC”) Mr. Adams and the affiliates participated on terms similar to those afforded other non-affiliated working interest owners. While the affiliates have generally maintained their existing property interest, they have not participated in any such transactions originating after the death of Mr. Adams in October 2013. In connection with the operation of certain oil and gas properties, the Company also charges such related parties for administrative overhead primarily as prescribed by the Council of Petroleum Accountants Society Bulletin 5. The Company also enters into certain transactions in the normal course of business with other affiliated entities including direct cost reimbursement for shared phone and administrative services. In addition, the Company leases office space from an affiliated entity based on a lease rental rate determined by an independent appraisal.

The Company utilizes its former affiliate, Bencap, to administer certain of its employee medical benefit programs including a detail audit of individual medical claims. See Note (1) to the accompanying financials under the caption “Investments” for further discussion. Bencap earns a fee from the Company for providing such services at a discounted amount from its standard charge to non-affiliates. In February 2017, Bencap requested additional funding of approximately $0.5 million and the Company declined the additional funding request, resulting in forfeiture of the investment.

Activities with affiliates were as follows (in thousands):

	Three Months Ended
	March 31,
	2017		2016
Overhead recoveries	$	-	$	21

Affiliate billings to company	$	12	$	11

Company billings to affiliates	$	1	$	1

Rentals paid to affiliate	$	167	$	163

Fees paid to Bencap	$	108	$	36

Note 5 - Commitments and Contingencies

Under the Company’s automobile and workers’ compensation insurance policies, the Company can either receive a return of premium paid or be assessed for additional premiums up to pre-established limits. Additionally, in certain instances the risk of insured losses is shared with a group of similarly situated entities. The Company has appropriately recognized estimated expenses and liabilities related to these policies for losses incurred but not reported to the Company or its insurance carrier as follows (in thousands):

	March 31,		December 31,
	2017		2016
Estimated expenses and liabilities	$	2,504	$	2,657

The Company maintains 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. The Company also maintains third party insurance stop-loss coverage for aggregate medical claims exceeding $4.5 million. Medical accrual amounts are as follows (in thousands):

	March 31,		December 31,
	2017		2016
Accrued medical claims	$	1,923	$	1,411

Adams Resources Exploration Corporation (“AREC”) is named as a defendant in a number of Louisiana lawsuits involving alleged environmental contamination from prior drilling operations. Such suits typically allege improper disposal of oilfield wastes in earthen pits, with one matter involving allegations that drilling operations in 1986 contributed to the formation of a sinkhole in 2012 (the “Sinkhole Cases”). The Sinkhole Cases, while arising from a singular event, include a number of different lawsuits brought in Louisiana State Court and one consolidated action in the United States District Court for the Eastern District of Louisiana. In addition to the Sinkhole Cases, AREC is currently involved in two other such suits. These suits are styled LePetit Chateau Deluxe v. Adams Resources Exploration Corporation dated March 2004, and Henning Management, LLC v. Adams Resources Exploration Corporation dated November 2013. Each suit involves multiple industry defendants with substantially larger proportional interest in the properties. In addition, the Sinkhole Cases involve a number of defendants in the solution mining industry, in which AREC has never participated. In the LePetit Chateau Deluxe matter, all the larger defendants have settled the case. The plaintiffs in each of these matters are seeking unspecified compensatory and punitive damages. While management does not believe that a material adverse effect on the Company will result from the claims, significant attorney fees may be incurred by AREC to address claims related to these suits. As of March 31, 2017 and December 31, 2016, the Company has accrued $0.5 million of future legal/or settlement costs for these matters.

From time to time as incidental to its operations, the Company may become involved in various lawsuits and/or disputes. Primarily as an operator of an extensive trucking fleet, the Company is a party to motor vehicle accidents, worker compensation claims and other items of general liability as would be typical for the industry. Management of the Company is presently unaware of any claims against the Company that are either outside the scope of insurance coverage or that may exceed the level of insurance coverage and could potentially represent a material adverse effect on the Company’s financial position or results of operations.

Note 6 – Subsequent Event

On April 21, 2017 AREC, a wholly owned subsidiary of the Company, filed a petition under Chapter 11 of the United States Bankruptcy Code in the Bankruptcy Court for the District of Delaware, Case Number 17-10866(KG). AREC will continue to operate its business as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provision of the Bankruptcy Code and orders of the Bankruptcy Court. As of March 31, 2017, the estimated net realizable value of the oil and gas assets is anticipated to be greater than the net book value. The Company will continue to evaluate the estimated net realizable value until the sale process has concluded. Adams Resources & Energy, Inc. is the primary creditor in the Chapter 11 process.

On May 3, 2017, AREC filed a Motion with the Bankruptcy Court for approval of an auction process and engagement of Oil & Gas Asset Clearinghouse to conduct the auction. Over the past few years, the Company has de-emphasized its upstream operations and does not expect this Chapter 11 filing by its subsidiary to have a material adverse impact on any of its core businesses.

Item 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Results of Operations

Marketing

Marketing segment revenues, operating earnings, depreciation and certain costs were as follows (in thousands):

	Three Months Ended
	March 31,
	2017		2016		Change⁽¹⁾

Revenues	$	288,615	$	236,394		22.1	%

Operating earnings	$	1,393	$	4,648		(70.0	)%

Depreciation	$	2,069	$	2,689		(23.1	)%

Driver commissions	$	3,062	$	4,508		(32.1	)%

Insurance	$	1,239	$	2,171		(42.9	)%

Fuel	$	1,354	$	1,672		(19.0	)%

_________________________________

⁽¹⁾	Represents the percentage increase (decrease) from the prior year.

Crude oil marketing revenues increased in the first quarter of 2017 as a result of an increase in the market price for crude oil. The increase in crude oil prices offset the decline in marketing volumes. Operating earnings were adversely affected by the volume declines, inventory valuation changes as well as a narrowing of margins during the first quarter of 2017. Toward the end of the first quarter of 2017 we began to see an uplift in volumes as activity in our marketing areas has increased in recent months. Driver commissions are reduced due to the decline in volumes. Insurance costs are lower as a result of favorable safety performance. Fuel costs are lower consistent with reduced marketing volumes as compared to the first quarter of 2016.

Supplemental volume and price information is as follows:

	Three Months Ended
	March 31,
	2017		2016
Field Level Purchase Volumes – Per day⁽¹⁾
Crude oil – barrels		66,374		88,183

Average Purchase Price
Crude oil – per barrel	$	49.02	$	29.21

_____________________________

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

Crude Oil – Field Level Operating Earnings (Non GAAP-Measure)⁽¹⁾

Two significant factors affecting comparative crude oil marketing segment operating earnings are inventory valuations and forward commodity contract (derivatives or mark-to-market) valuations. As a purchaser and shipper of crude oil, the Company holds inventory in storage tanks and third-party pipelines. During periods of increasing crude oil prices, the Company recognizes inventory liquidation gains while during periods of falling prices, the Company recognizes inventory valuation losses.

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

The impact on crude oil segment operating earnings of inventory liquidations and derivative valuations is summarized as follows in reconciling from the GAAP to non-GAAP financial measures (in thousands):

	Three Months Ended
	March 31,
	2017			2016
As reported segment operating earnings	$	1,393		$	4,648
Add (less) -
Inventory valuation (gains) losses		658			(2,202	)
Derivative valuation (gains) losses		(420	)		158

Field level operating earnings⁽¹⁾	$	1,631		$	2,604

____________________________________

⁽¹⁾	Such designation is (a) unique to the Company, (b) not a substitute for GAAP and (c) not comparable to any similar measures developed by industry participants. The Company utilizes such data to evaluate the profitability of its operations.

The Company held crude oil inventory at a weighted average commodity price in barrels as follows:

	March 31, 2017				December 31, 2016
			Average				Average
	Barrels		Price		Barrels		Price
Crude oil inventory		413,527	$	49.88		255,146	$	51.22

Field level operating earnings and field level purchase volumes (see earlier table) depict the Company’s day-to-day operation of acquiring crude oil at the wellhead, transporting the material, and delivery to market at the sales point. Comparative field level operating earnings decreased during the first quarter of 2017 relative to the first quarter of 2016 due to reduced purchase volumes and reduced unit margins. Competition has remained strong, but we are beginning to see an uplift in volumes as activity in our marketing areas has increased in recent months.

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 the Company’s Annual Report for the year ended December 31, 2016.

- Transportation

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

	Three Months Ended
	March 31,
	2017			2016		Change⁽¹⁾

Revenues	$	13,455		$	13,347		0.8	%

Operating (loss) earnings	$	(298	)	$	173		(272.3	)%

Depreciation	$	1,591		$	1,985		(19.8	)%

Driver commissions	$	2,836		$	2,881		(1.6	)%

Insurance	$	1,381		$	1,481		(6.8	)%

Diesel fuel	$	1,632		$	1,311		24.5	%

Maintenance expense	$	1,638		$	1,327		23.4	%

Mileage		5,618			5,668		(0.9	)%

__________________________

⁽¹⁾Represents the percentage increase (decrease) from the prior year.

The Company’s revenue rate structure includes a component for fuel costs such that fuel cost fluctuations are largely passed through to the customer over time. To illustrate, a calculation of revenues net of fuel cost is presented below (in thousands):

	Three Months Ended
	March 31,
	2017			2016
Total transportation revenue	$	13,455		$	13,347
Diesel fuel cost		(1,632	)		(1,311	)
Revenues net of fuel⁽¹⁾	$	11,823		$	12,036

__________________________

⁽¹⁾Revenues net of fuel is a non-GAAP measure and utilized for internal analysis.

Revenues net of fuel are reduced in the first quarter of 2017 because of competition within the transportation segment. The Company began to see an uptick in activity toward the end of the first quarter of 2017 and continues to work on its strategy of streamlining operations and diversifying offerings in the transportation segment.

- Oil and Gas

Oil and gas segment revenues and operating earnings (loss) are primarily a function of crude oil and natural gas prices and volumes. Comparative amounts for revenues, operating earnings and depreciation and depletion are as follows (in thousands):

	Three Months Ended
	March 31,
	2017			2016			Change⁽¹⁾
Revenues	$	1,017		$	790			28.7	%

Operating loss	$	(42	)	$	(282	)		(85.1	)%

Depreciation and depletion	$	309		$	441			(29.9	)%

Dry hole expense	$	-		$	-			-	%

Producing property impairments	$	-		$	1			(100.0	)%

Prospect impairments	$	3		$	28			(89.3	)%

________________________________

⁽¹⁾	Represents the percentage increase (decrease) from the prior year.

Oil and gas revenues and operating earnings increased in the comparative first quarter of 2017 as commodity price increases offset production declines. Volumes declined consistent with reduced drilling activity. Depreciation and depletion expense is calculated on a units of production basis and is lower primarily due to a reduction in production volumes.

Production volumes and price information is as follows:

	Three Months Ended
	March 31,
	2017		2016
Crude Oil
Volume – barrels		8,474		10,071
Average price per barrel	$	48.78	$	29.17

Natural gas
Volume – mcf		140,707		197,433
Average price per mcf	$	2.99	$	1.95

Natural gas liquids
Volume – barrels		7,293		11,476
Average price per barrel	$	25.00	$	9.68

-	General and administrative

General and administrative expenses increased from $2.2 million during the first quarter of 2016 to $2.6 million during the first quarter of 2017 due to utilization of outside consultants as the Company conducted its review of strategic alternatives for the oil and gas exploration and production subsidiary.

-	Investments

During the third quarter of 2016, the Company completed a review of its equity method investment in Bencap and determined there was an other than temporary impairment. Underlying this decision are the terms of the investment agreement where Bencap has the option to request borrowings up to $1.5 million (on or after December 5, 2016 but before October 31, 2018) that the Company must provide or forfeit its 30% member interest. During the third quarter of 2016, management of the Company determined that it was unlikely to provide additional funding due to Bencap’s lower than projected revenue growth and operating losses since investment inception. As a result, the Company recognized a net loss of $1.4 million from its investment in Bencap as of September 30, 2016. This loss included a pre-tax impairment charge of $1.7 million and pre-tax losses from the equity method investment of $0.5 million. In February 2017, Bencap requested additional funding of approximately $0.5 million and the Company declined the additional funding request and forfeited its 30% member interest in BenCap.

Outlook

The Company plans to operate its segments with internally generated cash flows during 2017, but plans to remain flexible as the focus will be on business development opportunities. During 2017, the Company plans to leverage its investment in the transportation segment’s Houston terminal with the continued efforts to diversify service offerings, grow in new or existing areas with its marketing segment and complete the exit of the upstream oil and gas business.

Liquidity and Capital Resources

The Company’s liquidity derives from net cash provided by operating activities and is therefore dependent on the success of future operations. The most significant source of liquidity is the cash yield from net earnings factoring in the non-cash book expense items for depreciation, depletion, amortization and impairments. The Company has no debt and funds all of its projects from this stream of cash. In most periods, cash inflows equal or exceed capital spending outflows. Should cash inflow subside or turn negative, the Company will curtail its capital spending accordingly.

As of March 31, 2017 and December 31, 2016, the Company had no bank debt or other forms of debenture obligations. Cash balances are maintained in order to meet the timing of day-to-day cash needs and such amounts and working capital, the excess of current assets over current liabilities, were as follows (in thousands):

	March 31,		December 31,
	2017		2016
Cash	$	98,073	$	87,342

Working capital	$	107,777	$	106,444

Cash provided from operating activities was as follows (in thousands):

	Three Months Ended
	March 31,
	2017		2016
Net cash provided by (used in) operating activities	$	12,150	$	(2,358	)

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

The Company relies heavily on its ability to obtain open-line trade credit from its suppliers especially with respect to its crude oil marketing operation. During the fourth quarter of 2016, the Company elected to make several early payments in its crude oil marketing. The Company’s cash balance increased by approximately $12 million as of March 31, 2017 relative to the year ended December 31, 2016 as the year end 2016 balance was slightly lower than normal as a result of early payments made during the fourth quarter of 2016.

The Company maintains a stand-by letter of credit facility with Wells Fargo Bank to provide for the issuance of up to $60 million in stand-by letters of credit for the benefit of suppliers of crude oil. Stand-by letters of credit are issued as needed and are cancelled as the underlying purchase obligations are satisfied by cash payment when due. The issuance of stand-by letters of credit enables the Company to avoid posting cash collateral when procuring crude oil supply.

Early payments, collateral and letters of credit amounts were as follows (in thousands):

	March 31,		December 31,
	2017		2016
Early payments received	$	14,347	$	15,032
Cash collateral received	$	-	$	-
Prepayments to suppliers	$	-	$	-
Early payments to suppliers	$	2,743	$	14,382
Letters of credit outstanding	$	-	$	-

Management believes current cash balances, together with expected cash generated from future operations, and the ease of financing truck and trailer additions through leasing arrangements (should the need arise) will be sufficient to meet short-term and long-term liquidity needs.

The Company utilizes cash from operations to make discretionary investments in its marketing, transportation and exploration businesses. With the exception of commitments totaling approximately $7.2 million associated with barge affreightment contracts, storage tank terminal arrangements and office lease space, the Company’s future commitments and planned investments can be readily curtailed if operating cash flows contract.

Capital project spending through the first three months of 2017 is as follows (in thousands):

	Expended through
	March 31, 2017

Crude oil marketing	$	82
Truck transportation		102
Oil and gas exploration		822
	$	1,006

A quarterly dividend of $0.22 per common share or $928,000 was paid during each of the first quarters of 2017 and 2016. The most significant item affecting future increases or decreases in liquidity is earnings from operations and such earnings are dependent on the success of future operations. See Part I, Item 1A Risk Factors in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016.

Critical Accounting Policies and Use of Estimates

There have been no material changes to the Company’s ‟Critical Accounting Policies and Use of Estimates” disclosures that have occurred since the disclosures provided in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

There have been no material changes to the Company’s ‟Quantitative and Qualitative Disclosures about Market Risk” that have occurred since the disclosures provided in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016.

Forward-Looking Statements – Safe Harbor Provisions

This quarterly report for the period ended March 31, 2017 contains certain “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”). To the extent such statements are not recitations of historical fact, forward-looking statements involve risks and uncertainties. In particular, statements included herein and/or in the Company’s latest Annual Report on Form 10-K under the captions (a) Production and Reserve Information, (b) Regulatory Status and Potential Environmental Liability, (c) Management’s Discussion and Analysis of Financial Condition and Results of Operations, (d) Critical Accounting Policies and Use of Estimates, (e) Quantitative and Qualitative Disclosures about Market Risk, (f) Income Taxes, (g) Concentration of Credit Risk, (h) Fair Value Contract Activities, and (i) Commitments and Contingencies, among others, contain forward-looking statements. Where the Company expresses an expectation or belief regarding future results of events, such expression is made in good faith and believed to have a reasonable basis in fact. However, there can be no assurance that such expectation or belief will actually result or be achieved.

All forward-looking statements speak only as of the date of this Quarterly Report. You should not place undue reliance on these forward-looking statements. These forward-looking statements are subject to a number of risks, uncertainties and assumptions. Moreover, we operate in a very competitive and rapidly changing environment. New risks emerge from time to time. It is not possible for our management to predict all risks, nor can we assess the impact of all factors on our business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements we may make. Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this Quarterly Report are reasonable, we can give no assurance that these plans, intentions or expectations will be achieved or occur, and actual results could differ materially and adversely from those anticipated or implied by the forward-looking statements.

With the uncertainties of forward looking statements in mind, the reader should consider the risks discussed elsewhere in this report and other documents filed with the Securities and Exchange Commission from time to time and the important factors described in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016, under ‟Item 1A Risk Factors” that could cause actual results to differ materially from those expressed in any forward-looking statement made by or on behalf of the Company.

Item 4. Disclosure Controls and Procedures

The Company maintains ‟disclosure controls and procedures” (as defined in Rule 13a-15(e) and 15d-15(e) under the ‟Exchange Act”), that are designed to ensure that information required to be disclosed in the reports that the Company files or submits under the Exchange Act are recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and is accumulated and communicated to management, including the Company’s Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely discussions regarding required disclosure. Management necessarily applied its judgment in assessing the costs and benefits of such controls and procedures, which, by their nature, can provide only reasonable assurance regarding management’s disclosure control objectives.

As of the end of the period covered by this Quarterly Report, an evaluation was carried out under the supervision and with the participation of the Company’s management, including the Company’s Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures. Based upon that evaluation, the Chief Executive Officer and the Chief Financial Officer concluded the Company’s disclosure controls and procedures were not effective because of the material weakness in our internal control over financial reporting, as described in Management’s Report on Internal Control over Financial Reporting in Item 9A of our Annual Report on Form 10-K for the year ended December 31, 2016, continues to exist as of March 31, 2017.

Remediation of Material Weakness in Internal Control over Financial Reporting

We have taken and are continuing to take actions to improve our internal controls over financial reporting, including advancing previously identified initiatives to address our material weakness. The actions we have taken and are continuing to take are subject to ongoing senior management review. These remediation actions include:

·	Performing a review to ensure that no personnel signs off as the reviewer and subsequently posts the journal entry to the general ledger.

·	Considering repositioning the personnel in the financial close group to allow for more segregation of duties within the group.

·	Addressing the control gap relating to the segregation of duties by requiring review of the manual journal entry to occur after the journal entry is independently posted. Review after posting restricts the ability to edit the journal entry.

While the remediation actions are in process, the action will take time to be fully integrated and confirmed as effective and sustainable. Until the remediation steps are fully implemented and tested, the material weakness described above will continue to exist.

Changes in Internal Control over Financial Reporting

Other than what is stated above, there have not been any changes in the Company’s internal control over financial reporting during the fiscal quarter ended March 31, 2017 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

AREC is named as a defendant in a number of Louisiana lawsuits involving alleged environmental contamination from prior drilling operations. Such suits typically allege improper disposal of oilfield wastes in earthen pits, with one matter involving allegations that drilling operations in 1986 contributed to the formation of a sinkhole in 2012 (the “Sinkhole Cases”). The Sinkhole Cases, while arising from a singular event, include a number of different lawsuits brought in Louisiana State Court and one consolidated action in the United States District Court for the Eastern District of Louisiana. In addition to the Sinkhole Cases, AREC is currently involved in two other such suits. These suits are styled LePetit Chateau Deluxe v. Adams Resources Exploration Corporation dated March 2004, and Henning Management, LLC v. Adams Resources Exploration Corporation dated November 2013. Each suit involves multiple industry defendants with substantially larger proportional interest in the properties. In addition, the Sinkhole Cases involve a number of defendants in the solution mining industry, in which AREC has never participated. In the LePetit Chateau Deluxe matter, all the larger defendants have settled the case. The plaintiffs in each of these matters are seeking unspecified compensatory and punitive damages. While management does not believe that a material adverse effect on the Company will result from the claims, significant attorney fees may be incurred by AREC to address claims related to these suits. As of March 31, 2017 and December 31, 2016, the Company has accrued $0.5 million of future legal/or settlement costs for these matters.

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 Annual Report 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 are no material changes in the Company’s risk factors from those disclosed in the Company’s Annual Report for the year ended December 31, 2016 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

Item 6.	Exhibits

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

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, 2017	By /s/Thomas S. Smith
	Thomas S. Smith
	President, Chief Executive Officer
	(Principal Executive Officer)


	By /s/Josh C. Anders
	Josh C. Anders
	Chief Financial Officer
	(Principal Financial Officer and Principal
	Accounting Officer)

EXHIBIT INDEX

Exhibit
Number	Description

3(a)	Certificate of Incorporation of the Company, as amended. (Incorporated by reference to Exhibit 3(a) filed with the Annual Report on Form 10-K of the Company for the fiscal year ended December 31, 1987).
3(b)	Bylaws of the Company, as amended. (Incorporated by reference to Exhibit 3(b) filed with the Annual Report on Form 10-K for the year ended December 31, 2012 (-File No. 1-7908).
* 31.1	Certificate of Chief Executive 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

* 31.2	Certificate 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	Certificate of Chief Executive Officer pursuant to 18. U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

* 32.2	Certificate 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.INS-	XBRL Instance Document

* **101.SCH -	XBRL Taxonomy Extension Schema Document

* **101.CAL -	XBRL Taxonomy Extension Calculation Linkbase Document

* **101.DEF -	XBRL Taxonomy Extension Definition Linkbase Document

* **101.LAB -	XBLR Taxonomy Extension Label Linkbase Document
* **101.PRE -	XBRL Taxonomy Extension Presentation Linkbase Document

*	Exhibits filed herewith

Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) the Consolidated Statements of Income – Three Months Ended March 31, 2017 and 2016, (ii) the Consolidated Balance Sheets – March 31, 2017 and December 31, 2016, (iii) the Consolidated Statements of Cash Flows – Three Months Ended March 31, 2017 and 2016 and (iv) Notes to Consolidated Financial Statements.