Delek US Holdings, Inc. - Quarter Report: 2018 September (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)



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

		For the quarterly period ended September 30, 2018



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 001-38142

DELEK US HOLDINGS, INC.

(Exact name of registrant as specified in its charter)



Delaware		35-2581557
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

7102 Commerce Way, Brentwood, Tennessee 37027

(Address of principal executive offices) (Zip Code)

(615) 771-6701

(Registrant’s telephone number, including area code)

Not Applicable

(Former name, former address and former fiscal year, if changed since last report)

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

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

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," "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act.



Large accelerated filer þ	Accelerated filer o	Non-accelerated filer o	Smaller reporting company o	Emerging growth company o

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

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

At November 2, 2018, there were 81,948,413 shares of common stock, $0.01 par value, outstanding (excluding securities held by, or for the account of, the Company or its subsidiaries).

Table of Contents

Delek US Holdings, Inc.

Quarterly Report on Form 10-Q

For the Quarterly Period Ended September 30, 2018



PART I. FINANCIAL INFORMATION
Item 1. Financial Statements (unaudited)	3
Condensed Consolidated Balance Sheets	3
Condensed Consolidated Statements of Income	4
Condensed Consolidated Statements of Comprehensive Income	5
Condensed Consolidated Statements of Cash Flows	6
Notes to Condensed Consolidated Financial Statements	7
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	44
Item 3. Quantitative and Qualitative Disclosures about Market Risk	83
Item 4. Controls and Procedures	85

PART II. OTHER INFORMATION
Item 1. Legal Proceedings	86
Item 1A. Risk Factors	86
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	86
Item 5. Other Information	86
Item 6. Exhibits	88
Signatures	89

Financial Statements

Part I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

Delek US Holdings, Inc.

Condensed Consolidated Balance Sheets (Unaudited)

(In millions, except share and per share data)



	September 30, 2018			December 31, 2017
ASSETS
Current assets:
Cash and cash equivalents	$	1,109.1		$	931.8
Accounts receivable, net	736.9			579.6
Accounts receivable from related parties	3.1			2.1
Inventories, net of inventory valuation reserves	923.9			808.4
Assets held for sale	—			160.0
Other current assets	88.4			129.9
Total current assets	2,861.4			2,611.8
Property, plant and equipment:
Property, plant and equipment	2,897.2			2,772.5
Less: accumulated depreciation	(754.8		)	(631.7		)
Property, plant and equipment, net	2,142.4			2,140.8
Goodwill	857.8			816.6
Other intangibles, net	105.8			101.1
Equity method investments	131.3			138.1
Other non-current assets	60.0			126.8
Total assets	$	6,158.7		$	5,935.2
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	1,108.1			$	973.4
Accounts payable to related parties	2.2			1.7
Current portion of long-term debt	32.0			590.2
Obligation under Supply and Offtake Agreements	478.7			435.6
Liabilities associated with assets held for sale	—			105.9
Accrued expenses and other current liabilities	384.6			564.9
Total current liabilities	2,005.6			2,671.7
Non-current liabilities:
Long-term debt, net of current portion	1,830.0			875.4
Environmental liabilities, net of current portion	136.1			68.9
Asset retirement obligations	76.9			72.1
Deferred tax liabilities	175.2			199.9
Other non-current liabilities	37.8			83.0
Total non-current liabilities	2,256.0			1,299.3
Stockholders’ equity:
Preferred stock, $0.01 par value, 10,000,000 shares authorized, no shares issued and outstanding	—			—
Common stock, $0.01 par value, 110,000,000 shares authorized, 90,432,492 shares and 81,533,548 shares issued at September 30, 2018 and December 31, 2017, respectively	0.9			0.8
Additional paid-in capital	1,168.8			900.1
Accumulated other comprehensive income	6.4			6.9
Treasury stock, 8,302,905 shares and 762,623 shares, at cost, as of September 30, 2018 and December 31, 2017, respectively	(356.3		)	(25.0		)
Retained earnings	901.5			767.8
Non-controlling interests in subsidiaries	175.8			313.6
Total stockholders’ equity	1,897.1			1,964.2
Total liabilities and stockholders’ equity	$	6,158.7		$	5,935.2

See accompanying notes to condensed consolidated financial statements

Financial Statements

Delek US Holdings, Inc.

Condensed Consolidated Statements of Income (Unaudited)

(In millions, except share and per share)



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2018			2017			2018			2017
Net revenues	$	2,495.2		$	2,370.6		$	7,411.9		$	4,783.4
Cost of sales:
Cost of materials and other	1,970.5			2,017.2			6,190.1			4,210.7
Operating expenses (excluding depreciation and amortization presented below)	136.4			126.7			400.7			248.5
Depreciation and amortization	41.2			40.1			119.3			93.2
Total cost of sales	2,148.1			2,184.0			6,710.1			4,552.4
Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below)	27.6			26.5			78.9			28.0
General and administrative expenses	58.0			68.0			176.1			122.0
Depreciation and amortization	8.0			6.8			27.1			12.2
Other operating (income) expense, net	(1.7		)	0.7			(9.4		)	1.0
Total operating costs and expenses	2,240.0			2,286.0			6,982.8			4,715.6
Operating income	255.2			84.6			429.1			67.8
Interest expense	31.2			34.1			95.2			62.5
Interest income	(1.4		)	(0.9		)	(3.0		)	(2.7		)
Income from equity method investments	(4.0		)	(5.1		)	(6.9		)	(9.7		)
Gain on remeasurement of equity method investment	—			(190.1		)	—			(190.1		)
Gain on sale of business	—			—			(13.2		)	—
Impairment loss on assets held for sale	—			—			27.5			—
Loss on extinguishment of debt	0.1			—			9.1			—
Other (income) expense, net	(7.5		)	(5.4		)	(7.9		)	(5.3		)
Total non-operating expenses (income), net	18.4			(167.4		)	100.8			(145.3		)
Income from continuing operations before income tax expense	236.8			252.0			328.3			213.1
Income tax expense	51.0			133.5			66.8			111.5
Income from continuing operations, net of tax	185.8			118.5			261.5			101.6
Discontinued operations:
Income (loss) from discontinued operations, including gain (loss) on sale of discontinued operations	0.8			(6.4		)	(10.7		)	(6.4		)
Income tax expense (benefit)	0.3			(2.3		)	(2.2		)	(2.3		)
Income (loss) from discontinued operations, net of tax	0.5			(4.1		)	(8.5		)	(4.1		)
Net income	186.3			114.4			253.0			97.5
Net income attributed to non-controlling interests	6.5			10.0			29.0			19.8
Net income attributable to Delek	$	179.8		$	104.4		$	224.0		$	77.7
Basic income per share:
Income from continuing operations	$	2.15		$	1.35		$	2.89		$	1.20
Income (loss) from discontinued operations	$	0.01		$	(0.05	)	$	(0.20	)	$	(0.06	)
Total basic income per share	$	2.16		$	1.30		$	2.69		$	1.14
Diluted income per share:
Income from continuing operations	$	2.02		$	1.34		$	2.75		$	1.19
Income (loss) from discontinued operations	$	0.01		$	(0.05	)	$	(0.19	)	$	(0.06	)
Total diluted income per share	$	2.03		$	1.29		$	2.56		$	1.13
Weighted average common shares outstanding:
Basic	83,575,122			80,581,762			83,294,473			68,272,918
Diluted	89,021,260			81,245,405			88,369,113			68,975,974
Dividends declared per common share outstanding	$	0.25		$	0.15		$	0.70		$	0.45

See accompanying notes to condensed consolidated financial statements

Financial Statements

Delek US Holdings, Inc.

Condensed Consolidated Statements of Comprehensive Income (Unaudited)

(In millions)



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
Net income attributable to Delek	$	179.8		$	104.4		$	224.0		$	77.7
Other comprehensive income (loss):
Commodity contracts designated as cash flow hedges:
Unrealized gains (losses), net of ineffectiveness gains of a nominal amount and $0.7 million for the three months and nine months ended September 30, 2018, respectively, and $0.1 million and $0.5 million for the three and nine months ended September 30, 2017, respectively	43.1			3.4			(28.9		)	(6.4		)
Realized losses (gains) reclassified to cost of materials and other	9.6			(1.0		)	18.4			38.5
Increase (decrease) related to commodity cash flow hedges, net	52.7			2.4			(10.5		)	32.1
Income tax (expense) benefit	(11.0		)	(0.8		)	2.3			(11.2		)
Net comprehensive income (loss) on commodity contracts designated as cash flow hedges	41.7			1.6			(8.2		)	20.9

Interest rate contracts designated as cash flow hedges:
Unrealized gains (losses)	—			0.1			(1.3		)	0.1
Realized losses reclassified to interest expense	—			0.1			0.7			0.1
Increase (decrease) related to interest rate cash flow hedges, net	—			0.2			(0.6		)	0.2
Income tax (expense) benefit	—			(0.1		)	0.1			(0.1		)
Net comprehensive income (loss) on interest rate contracts designated as cash flow hedges	—			0.1			(0.5		)	0.1

Foreign currency translation gain (loss)	0.2			—			(0.4		)	—

Other comprehensive income from equity method investments, net of tax expense of $2.2 million for both the three and nine months ended September 30, 2017	—			4.1			—			4.1

Postretirement benefit plans:
Unrealized gain arising during the year related to:
Net actuarial gain	8.9			1.0			9.0			1.0
Curtailment and settlement gains	2.4			6.3			2.5			6.3
Gain reclassified to earnings:
Recognized due to curtailment and settlement	(2.4		)	(6.1		)	(2.5		)	(6.1		)
Increase related to postretirement benefit plans, net	8.9			1.2			9.0			1.2
Income tax expense	(2.0		)	(0.4		)	(2.0		)	(0.4		)
Net comprehensive income on postretirement benefit plans	6.9			0.8			7.0			0.8
Total other comprehensive income (loss)	48.8			6.6			(2.1		)	25.9
Comprehensive income attributable to Delek	$	228.6		$	111.0		$	221.9		$	103.6

See accompanying notes to condensed consolidated financial statements

Financial Statements

Delek US Holdings, Inc.

Condensed Consolidated Statements of Cash Flows (Unaudited)

(In millions)



	Nine Months Ended September 30,
	2018			2017
Cash flows from operating activities:
Net income	$	253.0		$	97.5
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	146.4			105.4
Amortization of above and below market leases, net	(1.1		)	—
Amortization of deferred financing costs and debt discount	7.4			5.3
Accretion of environmental liabilities and asset retirement obligations	2.6			0.4
Amortization of unfavorable contract liability	(2.2		)	(4.4		)
Deferred income taxes	(34.7		)	97.8
Income from equity method investments	(6.9		)	(9.7		)
Dividends from equity method investments	5.2			1.1
Loss on disposal of assets	1.3			1.0
Gain on remeasurement of equity method investment	—			(190.1		)
Loss on extinguishment of debt	9.1			—
Gain on sale of business	(13.2		)	—
Impairment of assets held for sale	27.5			—
Equity-based compensation expense	15.6			12.6
Loss from discontinued operations	8.5			4.1
Changes in assets and liabilities, net of acquisitions:
Accounts receivable	(112.7		)	(57.5		)
Inventories and other current assets	(78.7		)	(38.1		)
Fair value of derivatives	(64.1		)	18.9
Accounts payable and other current liabilities	50.5			6.6
Obligation under Supply and Offtake Agreement	32.2			64.1
Non-current assets and liabilities, net	(14.4		)	(35.4		)
Cash provided by operating activities - continuing operations	231.3			79.6
Cash used in operating activities - discontinued operations	(30.1		)	(7.2		)
Net cash provided by operating activities	201.2			72.4
Cash flows from investing activities:
Business combinations, net of cash acquired	—			200.5
Equity method investment contributions	(0.2		)	(4.8		)
Distributions from equity method investments	1.0			10.9
Purchases of property, plant and equipment	(228.0		)	(108.4		)
Purchase of intangible assets	(1.7		)	(5.5		)
Proceeds from sale of property, plant and equipment	5.4			—
Proceeds from sale of business	110.8			—
Proceeds from sales of discontinued operations	55.5			—
Cash (used in) provided by investing activities - continuing operations	(57.2		)	92.7
Cash provided by investing activities - discontinued operations	20.0			13.5
Net cash (used in) provided by investing activities	(37.2		)	106.2

Delek US Holdings, Inc.

Condensed Consolidated Statements of Cash Flows (Unaudited) (continued)

(In millions)



	Nine Months Ended September 30,
	2018			2017
Cash flows from financing activities:
Proceeds from long-term revolvers	1,749.1			781.7
Payments on long-term revolvers	(1,227.8		)	(920.5		)
Proceeds from term debt	690.6			248.1
Payments on term debt	(824.6		)	(79.9		)
Proceeds from product financing agreements	—			21.0
Repayments of product financing agreements	(72.4		)	(9.0		)
Taxes paid due to the net settlement of equity-based compensation	(10.8		)	(2.7		)
Repurchase of common stock	(207.4		)	—
Repurchase of non-controlling interest	—			(7.3		)
Distribution to non-controlling interest	(21.5		)	(23.8		)
Dividends paid	(58.8		)	(31.3		)
Deferred financing costs paid	(13.2		)	(6.1		)
Cash provided by (used in) financing activities - continuing operations	3.2			(29.8		)
Cash used in financing activities - discontinued operations	—			—
Net cash provided by (used in) financing activities	3.2			(29.8		)
Net increase in cash and cash equivalents	167.2			148.8
Cash and cash equivalents at the beginning of the period	941.9			689.2
Cash and cash equivalents at the end of the period	1,109.1			838.0
Less cash and cash equivalents of discontinued operations at the end of the period	—			6.3
Cash and cash equivalents of continuing operations at the end of the period	$	1,109.1		$	831.7



Supplemental disclosures of cash flow information:
Cash paid during the period for:
Interest, net of capitalized interest of $0.6 million and $0.2 million in the 2018 and 2017 periods, respectively	$	87.2		$	52.7
Income taxes	$	53.3		$	70.6
Non-cash investing activities:
Common stock issued in connection with the buyout of Alon Partnership non-controlling interest	$	127.0		$	—
(Decrease) increase in accrued capital expenditures	$	(17.1	)	$	2.4
Non-cash financing activities:
Common stock issued in connection with settlement of Convertible Notes	$	123.9		$	—
Treasury shares received in connection with exercise of Call Options	$	(123.9	)	$	—
Common stock issued in connection with the Delek/Alon Merger	$	—		$	509.0
Equity instruments issued in connection with the Delek/Alon Merger	$	—		$	21.7

See accompanying notes to condensed consolidated financial statements

Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 1 - Organization and Basis of Presentation

Delek US Holdings, Inc. operates through its consolidated subsidiaries, which include Delek US Energy, Inc. (and its subsidiaries) and Alon USA Energy, Inc. ("Alon") (and its subsidiaries).

Effective July 1, 2017 (the "Effective Time"), we acquired the outstanding common stock of Alon (previously listed under NYSE: ALJ) (the "Delek/Alon Merger", as further discussed in Note 2), resulting in a new post-combination consolidated registrant renamed as Delek US Holdings, Inc. (“New Delek”), with Alon and the previous Delek US Holdings, Inc. (“Old Delek”) surviving as wholly-owned subsidiaries. New Delek is the successor issuer to Old Delek and Alon pursuant to Rule 12g-3(c) under the Securities Exchange Act of 1934, as amended (the "Exchange Act"). In addition, as a result of the Delek/Alon Merger, the shares of common stock of Old Delek and Alon were delisted from the New York Stock Exchange ("NYSE") in July 2017, and their respective reporting obligations under the Exchange Act were terminated.

Unless otherwise indicated or the context requires otherwise, the disclosures and financial information included in this report for the periods prior to July 1, 2017 reflect that of Old Delek, and the disclosures and financial information included in this report for the periods beginning July 1, 2017 reflect that of New Delek. The terms "we," "our," "us," "Delek" and the "Company" are used in this report to refer to Old Delek and its consolidated subsidiaries for the periods prior to July 1, 2017, and New Delek and its consolidated subsidiaries for the periods on or after July 1, 2017, unless otherwise noted. New Delek's Common Stock is listed on the NYSE under the symbol "DK."

During the third quarter 2017, we committed to a plan to sell certain assets associated with our Paramount and Long Beach, California refineries and Alon's California renewable fuels facility (collectively, the "California Discontinued Entities"), which were acquired as part of the Delek/Alon Merger. As a result of this decision and commitment to a plan, and because it was made within three months of the Delek/Alon Merger, we met the requirements under Accounting Standards Codification ("ASC") 205-20, Presentation of Financial Statements - Discontinued Operations ("ASC 205-20") and ASC 360, Property, Plant and Equipment ("ASC 360") to report the results of the California Discontinued Entities as discontinued operations and to classify the California Discontinued Entities as a group of assets held for sale. On March 16, 2018, Delek sold to World Energy, LLC (i) all of Delek’s membership interests in AltAir Paramount, LLC (Alon's California renewable fuels facility), (ii) certain refining assets and other related assets located in Paramount, California and (iii) certain associated tank farm and pipeline assets and other related assets located in California. The transaction to dispose of certain assets and liabilities associated with our Long Beach, California refinery, to Bridge Point Long Beach, LLC, closed July 17, 2018. See Note 5 for further information regarding the California Discontinued Entities.

Our condensed consolidated financial statements include the accounts of Delek and its subsidiaries. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with U.S. Generally Accepted Accounting Principles ("GAAP") have been condensed or omitted, although management believes that the disclosures herein are adequate to make the financial information presented not misleading. Our unaudited condensed consolidated financial statements have been prepared in conformity with GAAP applied on a consistent basis with those of the annual audited financial statements included in our Annual Report on Form 10-K filed with the Securities and Exchange Commission ("SEC") on March 1, 2018 (the "Annual Report on Form 10-K") and in accordance with the rules and regulations of the SEC. These unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and the notes thereto for the year ended December 31, 2017 included in our Annual Report on Form 10-K.

Our condensed consolidated financial statements include Delek Logistics Partners, LP ("Delek Logistics"), Alon USA Partners, LP (the "Alon Partnership") and AltAir Paramount LLC ("AltAir"), all variable interest entities as of December 31, 2017. However, Delek acquired the non-controlling interest in the Alon Partnership on February 7, 2018 and sold AltAir on March 16, 2018. Thus, Delek Logistics is Delek's only remaining variable interest entity as of September 30, 2018. As the indirect owner of the general partner of Delek Logistics, we have the ability to direct the activities of this entity that most significantly impact its economic performance. We are also considered to be the primary beneficiary for accounting purposes for this entity and are Delek Logistics' primary customer. As Delek Logistics does not derive an amount of gross margin material to us from third parties, there is limited risk to Delek associated with Delek Logistics' operations. However, in the event that Delek Logistics incurs a loss, our operating results will reflect such loss, net of intercompany eliminations, to the extent of our ownership interest in this entity.

Notes to Condensed Consolidated Financial Statements (Unaudited)

In the opinion of management, all adjustments necessary for a fair presentation of the financial condition and the results of operations for the interim periods have been included. All significant intercompany transactions and account balances have been eliminated in consolidation. All adjustments are of a normal, recurring nature. Operating results for the interim period should not be viewed as representative of results that may be expected for any future interim period or for the full year.

Certain prior period amounts have been reclassified in order to conform to the current period presentation. Additionally, certain changes to presentation of the prior period statements of income have been made in order to conform to the current period presentation, primarily relating to the addition of a subtotal entitled 'cost of sales' which includes all costs directly attributable to the generation of the related revenue, as defined by GAAP, and the retitling of what was previously referred to as 'cost of goods sold' to 'cost of materials and other'. In connection with this change in presentation, we have revised our related accounting policy as follows:

Cost of Materials and Other and Operating Expenses

For the refining segment, cost of materials and other includes (i) the direct cost of materials (such as crude oil and other refinery feedstocks, refined petroleum products and blendstocks, and ethanol feedstocks and products) that are a component of our products sold; (ii) costs related to the delivery (such as shipping and handling costs) of products sold; (iii) costs related to our environmental credit obligations to comply with various governmental and regulatory programs (such as the cost of renewable identification numbers as required by the EPA’s Renewable Fuel Standard and emission credits under various cap-and-trade systems); and (iv) gains and losses on our commodity derivative instruments.

Operating expenses for the refining segment include the costs to operate our refineries and biodiesel facilities, excluding depreciation and amortization. These costs primarily include employee-related expenses, energy and utility costs, catalysts and chemical costs, and repairs and maintenance expenses.

For the logistics segment, cost of materials and other includes (i) all costs of purchased refined products, additives and related transportation of such products, (ii) costs associated with the operation of our trucking assets, which primarily include allocated employee costs and other costs related to fuel, truck leases and repairs and maintenance, (iii) the cost of pipeline capacity leased from a third-party, and (iv) gains and losses related to our commodity hedging activities.

Operating expenses for the logistics segment include the costs associated with the operation of owned terminals and pipelines and terminalling expense at third-party locations, excluding depreciation and amortization. These costs primarily include outside services, allocated employee costs, repairs and maintenance costs and energy and utility costs. Operating expenses related to the wholesale business are excluded from cost of sales because they primarily relate to costs associated with selling the products through our wholesale business.

For the retail segment, cost of materials and other comprises the costs related to specific products sold at retail sites, primarily consisting of motor fuels and merchandise. Retail fuel cost of sales represents the cost of purchased fuel, including transportation costs. Merchandise cost of sales includes the delivered cost of merchandise purchases, net of merchandise rebates and commissions. Operating expenses related to the retail business include costs such as wages of employees, lease expense, utility expense and other costs of operating the stores, excluding depreciation and amortization, and are excluded from cost of sales because they primarily relate to costs associated with selling the products through our retail sites.

Depreciation and amortization is separately presented in our statement of income and disclosed by reportable segment in Note 14.

New Accounting Pronouncements

In August 2018, the Financial Accounting Standards Board (the "FASB") issued guidance related to customers’ accounting for implementation costs incurred in a cloud computing arrangement that is considered a service contract. This pronouncement aligns the requirements for capitalizing implementation costs in such arrangements with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. This pronouncement is effective for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2019. Early adoption is permitted, including adoption in any interim period for which financial statements have not been issued. Entities can choose to adopt the new guidance prospectively or retrospectively. We expect to adopt this guidance on or before the effective date and are currently evaluating the impact that adopting this new guidance will have on our business, financial condition and results of operations.

In August 2018, the FASB issued guidance related to disclosure requirements for defined benefit plans. The pronouncement eliminates, modifies and adds disclosure requirements for defined benefit plans. The pronouncement is effective for fiscal years ending after December 15, 2020, and early adoption is permitted. We expect to adopt this guidance on or before the effective date and do not expect adopting this new guidance will have a material impact on our business, financial condition or results of operations.

In August 2018, the FASB issued guidance related to disclosure requirements for fair value measurements. The pronouncement eliminates, modifies and adds disclosure requirements for fair value measurements. The pronouncement is effective for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2019, with early adoption permitted. We expect to adopt this guidance on or before the effective date and do not expect adopting this new guidance will have a material impact on our business, financial condition or results of operations.

Notes to Condensed Consolidated Financial Statements (Unaudited)

In February 2018, the FASB issued guidance that allows a reclassification from accumulated other comprehensive income ("AOCI") to retained earnings for stranded tax effects resulting from the Tax Cuts and Jobs Act (the "Tax Reform Act"), which was signed into law on December 22, 2017. Consequently, the amendments eliminate the stranded tax effects related to items in accumulated other comprehensive income resulting from the Tax Reform Act. The new guidance may be applied retrospectively to each period in which the effect of the Tax Reform Act is recognized, or in the period of adoption. This guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. We elected to early adopt this guidance effective January 1, 2018. As a result of adopting this guidance, we reclassified $1.6 million from AOCI to retained earnings. The effect of the Tax Reform Act on temporary differences related to amounts initially recorded in AOCI are provisional. As we finalize the accounting for tax effects of the Tax Reform Act on the related temporary differences, additional reclassification adjustments may be recorded in future periods. See Note 11 for further discussion.

In August 2017, the FASB issued guidance to better align financial reporting for hedging activities with the economic objectives of those activities for both financial (e.g., interest rate) and commodity risks. The guidance was intended to create more transparency in the presentation of financial results, both on the face of the financial statements and in the footnotes, and simplify the application of hedge accounting guidance. This guidance is effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. Companies are required to apply the guidance on a modified retrospective transition method in which the cumulative effect of the change will be recognized within equity in the consolidated balance sheet as of the date of adoption. Early adoption is permitted, including in an interim period. If a company early adopts in an interim period, any adjustments should be reflected as of the beginning of the fiscal year that includes the interim period. We expect to adopt this guidance on or before the effective date and are currently evaluating the impact that adopting this new guidance will have on our business, financial condition and results of operations.

In May 2017, the FASB issued guidance that clarifies when changes to the terms or conditions of a share-based payment award must be accounted for as modifications. The modification accounting guidance applies if the value, vesting conditions or classification of the award changes. This guidance is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. This guidance should be applied prospectively to an award modified on or after the adoption date. We adopted this guidance on January 1, 2018 and the adoption did not have a material impact on our business, financial condition or results of operations.

In March 2017, the FASB issued guidance that will require that an employer disaggregate the service cost component from the other components of net benefit cost with respect to defined benefit postretirement employee benefit plans. Service cost is required to be reported in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net periodic benefit cost are required to be reported outside the subtotal for operating income. Additionally, only the service cost component of net benefit costs are eligible for capitalization. The guidance became effective January 1, 2018. We adopted this guidance on January 1, 2018, which will retrospectively impact the presentation of our third and fourth quarter 2017 statements of income as a result of the pension and postretirement obligations assumed in the Delek/Alon Merger. As further discussed in Note 18, only the service cost component of net periodic benefit costs are included as part of general and administrative expenses in the accompanying condensed consolidated statements of income. The other components of net periodic benefit costs are included as part of other non-operating expenses (income), net. As a practical expedient, we used the amounts disclosed regarding our pension and other postretirement benefit plans for the prior comparative periods as the estimation basis for applying the retrospective presentation requirements in our current Quarterly Report on Form 10-Q and will also do so in our 2018 Annual Report on Form 10-K. This will require recasting of prior periods subsequent to the Delek/Alon Merger. The following table details the impact of the retrospective adoption of this standard for the three and nine months ended September 30, 2017.



	Three Months Ended								Nine Months Ended
	September 30, 2017								September 30, 2017
(in millions)	As Reported		Adjustment			As Adjusted			As Reported		Adjustment			As Adjusted
General and administrative expenses	$	61.8	$	6.2		$	68.0		$	115.8	$	6.2		$	122.0
Other expense (income), net	$	0.8	$	(6.2	)	$	(5.4	)	$	0.9	$	(6.2	)	$	(5.3	)

In February 2017, the FASB issued guidance clarifying the scope of asset derecognition guidance and accounting for partial sales of nonfinancial assets. The amendments in this guidance should be applied using either i) a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption or ii) a retrospective basis to each period presented in the financial statements. This guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period. We adopted this guidance on January 1, 2018, and the adoption did not have a material impact on our business, financial condition or results of operations.

Notes to Condensed Consolidated Financial Statements (Unaudited)

In January 2017, the FASB issued guidance concerning the goodwill impairment test that eliminates Step 2, which required a comparison of the implied fair value of goodwill of the reporting unit with the carrying amount of that goodwill for that reporting unit. It also eliminates the requirements for any reporting unit with a zero or negative carrying amount to perform a qualitative assessment and, if it fails that qualitative assessment, to perform Step 2 of the goodwill impairment test. An entity still has the option to perform the qualitative assessment for a reporting unit to determine if the quantitative impairment test is necessary. This guidance is effective for annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. As permitted under Accounting Standards Update 2017-04, we expect to early adopt this guidance in the fourth quarter of 2018 in connection with our 2018 goodwill impairment tests to be performed as of October 31, 2018. We do not anticipate that the adoption will have a material impact on our business, financial condition or results of operations.

In October 2016, the FASB issued guidance that requires an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs. This guidance is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. We adopted this guidance on January 1, 2018. As a result of adopting this guidance, we decreased retained earnings by $29.9 million for the cumulative effect as of January 1, 2018.

In August 2016, the FASB issued guidance that clarifies eight cash flow classification issues pertaining to cash receipts and cash payments. This guidance is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. We adopted this guidance on January 1, 2018 and the adoption did not have a material impact on our business, financial condition or results of operations, except for reclassifications of certain distributions received from equity method investees, due to Delek making an accounting policy election to classify distributions received from equity method investees using the cumulative earnings approach. Under this approach, distributions received are considered returns on investment and classified as cash inflows from operating activities, unless the investor’s cumulative distributions received less distributions received in prior periods that were determined to be returns of investment exceed cumulative equity in earnings (as adjusted for amortization of basis differences) recognized by the investor. When such an excess occurs, the current-period distribution up to this excess should be considered a return of investment and classified as cash inflows from investing activities. This resulted in a reclassification of $10.9 million of distributions received in the nine months ended September 30, 2017 from the line item entitled dividends from equity method investments in net cash provided by (used in) operating activities to the line item entitled distributions from equity method investments in net cash provided by (used in) investing activities in the condensed consolidated statements of cash flows.

In June 2016, the FASB issued guidance requiring the measurement of all expected credit losses for financial assets held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. Financial institutions and other organizations will now use forward-looking information to better inform their credit loss estimates. This guidance is effective for interim and annual periods beginning after December 15, 2019. We expect to adopt this guidance on or before the effective date and are currently evaluating the impact that adopting this new guidance will have on our business, financial condition and results of operations.

In February 2016, the FASB issued guidance that requires the recognition of a lease liability and a right-of-use asset, initially measured at the present value of the lease payments, in the statement of financial condition for all leases with terms longer than one year. Subsequent guidance was issued to consider the impact of practical expedients. The guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. We plan to adopt the new lease standard on January 1, 2019. We plan to elect the package of practical expedients which, among other things, allows us to carry forward the historical lease classification. We plan to also elect the practical expedient not to separate lease and non-lease components, which allows us to combine the components if certain criteria are met. Further, we plan to elect the optional transition method, which allows us to recognize a cumulative-effect adjustment to the opening balance sheet of retained earnings at the date of adoption and to not recast our comparative periods. We do not plan to elect the hindsight practical expedients, which would have allowed us to use hindsight in determining the reasonably certain lease term.

As part of our efforts to prepare for adoption, beginning in 2018, we formed a project implementation team, as well as a project timeline, to evaluate the guidance. We have substantially completed our analysis of existing leases and the impact on our business processes and accounting systems. We continue to evaluate the impact of the guidance on our controls and financial statement disclosures, and expect to implement any changes to accommodate the new accounting and disclosure requirements prior to adoption on January 1, 2019. We anticipate adoption of the guidance will have a material impact on our consolidated balance sheet, but will not have a material impact on our consolidated income statement. We anticipate that the most significant impact will be the recognition of the lease liability and a right-of-use asset on our consolidated balance sheet.

Notes to Condensed Consolidated Financial Statements (Unaudited)

In January 2016, the FASB issued guidance that affects the accounting for equity investments, financial liabilities accounted for under the fair value option and the presentation and disclosure requirements for financial instruments. Under the new guidance, all equity investments in unconsolidated entities (other than those accounted for using the equity method of accounting) will generally be measured at fair value through earnings. There will no longer be an available-for-sale classification for equity securities with readily determinable fair values. For financial liabilities when the fair value option has been elected, changes in fair value due to instrument-specific credit risk will be recognized separately in other comprehensive income. It will require public business entities to use the exit price notion when measuring the fair value of financial instruments for disclosure purposes and separate presentation of financial assets and financial liabilities by measurement category and form of financial asset, and will eliminate the requirement for public business entities to disclose the method and significant assumptions used to estimate the fair value that is required to be disclosed for financial instruments measured at amortized cost. The new guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period. We adopted this guidance on January 1, 2018 and the adoption did not have a material impact on our business, financial condition or results of operations.

In May 2014, the FASB issued guidance as codified in Accounting Standards Codification ("ASC") 606, “Revenue from Contracts with Customers ("ASC 606),” to clarify the principles for recognizing revenue. The core principle of the new guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The guidance also requires improved interim and annual disclosures that enable the users of financial statements to better understand the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. The new guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period, and can be adopted retrospectively. We adopted this guidance on January 1, 2018, using the modified retrospective transition method applied to contracts which were not completed as of January 1, 2018, and the adoption did not have a material impact on our business, financial condition or results of operations.

The Company has updated its policies as it relates to revenue recognition. Revenue is measured based on consideration specified in a contract with a customer. The Company recognizes revenue when it satisfies a performance obligation by transferring control over a product or by providing services to a customer. The adoption of ASC 606 did not materially change our revenue recognition patterns, which are described below by reportable segment:

Refining

Revenues for products sold are recorded at the point of sale upon delivery of product, which is the point at which title to the product is transferred, the customer has accepted the product and the customer has significant risks and rewards of owning the product. We typically have a right to payment once control of the product is transferred to the customer. Transaction prices for these products are typically at market rates for the product at the time of delivery. Payment terms require customers to pay shortly after delivery and do not contain significant financing components.

Logistics

Revenues for products sold are generally recognized upon delivery of the product, which is when title and control of the product is transferred. Transaction prices for these products are typically at market rates for the product at the time of delivery. Service revenues are recognized as crude oil, intermediate and refined product are shipped through, delivered by or stored in our pipelines, trucks, terminals and storage facility assets, as applicable. We do not recognize product revenues for these services as the product does not represent a promised good in the context of ASC 606. All service revenues are based on regulated tariff rates or contractual rates. Payment terms require customers to pay shortly after delivery and do not contain significant financing components.

Retail

Fuel and merchandise revenue is recognized at the point of sale, which is when control of the product is transferred to the customer. Payments from customers are received at the time sales occur in cash or by credit or debit card. We derive service revenues from the sale of lottery tickets, money orders, car washes and other ancillary product and service offerings. Service revenue and related costs are recorded at gross amounts or net amounts, as appropriate, in accordance with the principal versus agent provisions in ASC 606.

Refer to Note 14 for disclosure of our revenue disaggregated by segment, as well as a description of our reportable segment operations.

Sales, Use and Excise Taxes

Upon the adoption of ASC 606, we made the accounting policy election to exclude from revenue all taxes assessed by a governmental authority, including sales, use and excise taxes, that are both imposed on and concurrent with a specific revenue-producing transaction and collected from a customer. Sales, use and excise taxes were also excluded from revenue historically in accordance with the applicable guidance in ASC 605, Revenue Recognition.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 2 - Acquisitions

In January 2017, we announced that Old Delek (and various related entities) entered into a merger agreement with Alon, as amended (the "Merger Agreement"). The related Merger (the "Merger" or the "Delek/Alon Merger") was effective July 1, 2017 (as previously defined, the “Effective Time”), resulting in a new post-combination consolidated registrant renamed as Delek US Holdings, Inc. (as previously defined, “New Delek”), with Alon and Old Delek surviving as wholly-owned subsidiaries of New Delek. New Delek is the successor issuer to Old Delek and Alon pursuant to Rule 12g-3(c) under the Exchange Act, as amended. In addition, as a result of the Delek/Alon Merger, the shares of common stock of Old Delek and Alon were delisted from the NYSE in July 2017, and their respective reporting obligations under the Exchange Act were terminated. Prior to the Merger, Old Delek owned a non-controlling equity interest of approximately 47% of the outstanding shares of Alon, which was accounted for under the equity method of accounting (See Note 4).

Subject to the terms and conditions of the Merger Agreement, at the Effective Time, each issued and outstanding share of Alon Common Stock, other than shares owned by Old Delek and its subsidiaries or held in the treasury of Alon, was converted into the right to receive 0.504 of a share of New Delek Common Stock, or, in the case of fractional shares of New Delek Common Stock, cash (without interest) in an amount equal to the product of (i) such fractional part of a share of New Delek Common Stock multiplied by (ii) $25.96 per share, which was the volume weighted average price of the Old Delek Common Stock, par value $0.01 per share as reported on the NYSE Composite Transactions Reporting System for the twenty consecutive NYSE full trading days ending on June 30, 2017. Each outstanding share of restricted Alon Common Stock was assumed by New Delek and converted into restricted stock denominated in shares of New Delek Common Stock, using the conversion rate applicable to the Merger. Committed but unissued share-based awards were exchanged and converted into rights to receive share-based awards indexed to New Delek Common Stock.

In addition, subject to the terms and conditions of the Merger Agreement, each share of Old Delek Common Stock or fraction thereof issued and outstanding immediately prior to the Effective Time (other than Old Delek Common Stock held in the treasury of Old Delek, which was retired in connection with the Merger) was converted at the Effective Time into the right to receive one validly issued, fully paid and non‑assessable share of New Delek Common Stock or such fraction thereof equal to the fractional share of New Delek Common Stock. All existing Old Delek stock options, restricted stock awards and stock appreciation rights were converted into equivalent rights with respect to New Delek Common Stock.

In connection with the Merger, Alon, New Delek and U.S. Bank National Association, as trustee (the “Trustee”) entered into a First Supplemental Indenture (the “Supplemental Indenture”), effective as of July 1, 2017, supplementing the Indenture, dated as of September 16, 2013 (the “Original Indenture” the Original Indenture, as amended by the Supplemental Indenture, is referred to as the "Indenture"), pursuant to which Alon issued its 3.00% Convertible Senior Notes due 2018 (the “Convertible Notes”), which were convertible into shares of Alon’s Common Stock, par value $0.01 per share or cash or a combination of cash and Alon Common Stock, all as provided in the Indenture. The Supplemental Indenture provided that, as of the Effective Time, the right to convert each $1,000 principal amount of the Convertible Notes based on a number of shares of Alon Common Stock equal to the Conversion Rate (as defined in the Indenture) in effect immediately prior to the Merger was changed into a right to convert each $1,000 principal amount of Convertible Notes into or based on a number of shares of New Delek Common Stock (at the exchange rate of 0.504), par value $0.01 per share, equal to the Conversion Rate in effect immediately prior to the Merger. In addition, the Supplemental Indenture provided that, as of the Effective Time, New Delek fully and unconditionally guaranteed, on a senior basis, Alon’s obligations under the Convertible Notes. See Note 8 for further discussion.

In connection with the Indenture, Alon also entered into equity instruments, including Call Options and Warrants, designed, in combination, to hedge a portion of the risk associated with the potential exercise of the conversion feature of the Convertible Notes and to mitigate the dilutive effect of such potential conversion. These equity instruments, in addition to the conversion feature, represented equity instruments originally indexed to Alon Common Stock that were exchanged for instruments with terms designed to preserve the original economic intent of such instruments and indexed to New Delek Common Stock in connection with the Merger. See Note 8 for further discussion.

Alon was a refiner and marketer of petroleum products, operating primarily in the south central, southwestern and western regions of the United States. In connection with the Delek/Alon Merger, Delek acquired 100% of the general partner and 81.6% of the limited partner interests in the Alon Partnership, which owns a crude oil refinery in Big Spring, Texas with a crude oil throughput capacity of 73,000 barrels per day ("bpd") and an integrated wholesale marketing business. Delek acquired the non-controlling interest in the Alon Partnership on February 7, 2018. In addition, as a result of the Delek/Alon Merger, Delek acquired a crude oil refinery in Krotz Springs, Louisiana with a crude oil throughput capacity of 74,000 bpd. In connection with the Delek/Alon Merger, Delek also acquired crude oil refineries in California, which have not processed crude oil since 2012. On March 16, 2018, Delek sold to World Energy, LLC the Paramount, California refinery and the California renewables facility (AltAir). The transaction to dispose of certain assets and liabilities associated with the Long Beach, California refinery, to Bridge Point Long Beach, LLC, closed July 17, 2018. Alon was a marketer of asphalt, which it distributed through asphalt terminals located predominantly in the southwestern and western United States. On May 21, 2018, Delek sold four asphalt terminals (included in Delek's corporate/other segment) and its 50% interest in an asphalt joint venture to an affiliate of Andeavor. See further discussion in Note 1 and Note 5. Finally, in connection with the Delek/Alon Merger, Delek acquired Alon's retail business where Alon was the largest 7-Eleven licensee in the United States operating approximately 300 convenience stores which market motor fuels in central and west Texas and New Mexico.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Transaction costs incurred by the Company in connection with the Delek/Alon Merger totaled $6.6 million for the nine months ended September 30, 2018 (none were incurred during the three months then ended ) and $18.4 million and $22.4 million for the three and nine months ended September 30, 2017, respectively. Such costs were included in general and administrative expenses in the accompanying condensed consolidated statements of income.

The Merger was accounted for using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their fair values as of the acquisition date.

The components of the consideration transferred were as follows (dollars in millions, except per share amounts):



Delek common stock issued	19,250,795
Ending price per share of Delek Common Stock immediately before the Effective Time	$	26.44
Total value of common stock consideration			$	509.0
Additional consideration⁽¹⁾			21.7
Fair value of Delek's pre-existing equity method investment in Alon ⁽²⁾			449.0
			$	979.7

The final allocation of the aggregate purchase price as of September 30, 2018 (which was finalized as of June 30, 2018) is summarized as follows (in millions), and is inclusive of the California Discontinued Entities discussed in Note 5:



Cash	$	215.3
Receivables	176.8
Inventories	266.3
Prepaids and other current assets	38.7
Property, plant and equipment ⁽³⁾	1,130.3
Equity method investments	31.0
Acquired intangible assets ⁽⁴⁾	86.7
Goodwill ⁽⁵⁾	870.7
Other non-current assets	37.0
Accounts payable	(263.4		)
Obligation under Supply & Offtake Agreements	(208.9		)
Current portion of environmental liabilities	(7.9		)
Other current liabilities	(308.6		)
Environmental liabilities and asset retirement obligations, net of current portion	(226.7		)
Deferred income taxes	(194.0		)
Debt	(568.0		)
Other non-current liabilities ⁽⁶⁾	(95.6		)
Fair value of net assets acquired	$	979.7


⁽¹⁾	Additional consideration includes the fair value of certain equity instruments originally indexed to Alon stock that were exchanged for instruments indexed to New Delek's stock, as well as the fair value of certain share-based payments that were required to be exchanged for awards indexed to New Delek's stock in connection with the Delek/Alon Merger.

⁽²⁾The fair value of Delek's pre-existing equity method investment in Alon was based on the quoted market price of shares of Alon.

⁽³⁾This fair value of property, plant and equipment is based on a valuation using a combination of the income, cost and market approaches. The useful lives are based upon guidelines for similar equipment, chronological age since installation and consideration of costs spent on upgrades, repairs, turnarounds and rebuilds.

⁽⁴⁾The acquired intangible assets amount includes the following identified intangibles:

•

Third-party fuel supply agreement intangible that is subject to amortization with a fair value of $49.0 million, which is being amortized over a 10-year useful life. We recognized amortization expense for the three and nine months ended September 30, 2018 of $1.2 million and $3.6 million, respectively. The estimated annual amortization is $4.9 million for the current and the four succeeding fiscal years.


•	Fuel trade name intangible valued at $4.0 million, which will be amortized over 5 years. We recognized amortization expense for the three and nine months ended September 30, 2018 of $0.2 million and $0.6 million, respectively. The estimated annual amortization is $0.8 million for the current and the three succeeding fiscal years, with $0.4 million in the fourth succeeding year.

Notes to Condensed Consolidated Financial Statements (Unaudited)


•	License agreements intangible valued at $2.6 million, which is being amortized over 8.7 years. We recognized amortization expense for the nine months ended September 30, 2018 of $0.1 million, as this intangible was sold in the first quarter of 2018.


•	Rights-of-way intangible valued at $9.5 million, which has an indefinite life.


•	Liquor license intangible valued at $8.5 million, which has an indefinite life.


•	Colonial Pipeline shipping rights intangible valued at $1.7 million, which has an indefinite life.


•	Refinery permits valued at $3.1 million, which have an indefinite life.


•	Below-market lease intangibles valued at $8.3 million, which is being amortized over the remaining lease term.

⁽⁵⁾Goodwill generated as a result of the Delek/Alon Merger consists of the value of expected synergies from combining operations, the acquisition of an existing integrated refining, marketing and retail business located in areas with access to cost–advantaged feedstocks with an assembled workforce that cannot be duplicated at the same costs by a new entrant, and the strategic advantages of having a larger market presence. The total amount of goodwill that is expected to be deductible for tax purposes is $15.5 million. Goodwill has been allocated to reportable segments based on various relevant factors. The updated allocation of goodwill to reportable segments in connection with the purchase price allocation is as follows: Refining - $801.3 million and Retail- $44.3 million. The remainder relates to the asphalt operations, which was included in the corporate, other and eliminations segment, and which was subsequently written off as part of the impairment on assets held for sale during the first quarter of 2018.

⁽⁶⁾The assumed other non-current liabilities include liabilities related to above-market leases fair valued at $15.8 million, which is being amortized over the remaining lease term.

The following unaudited pro forma financial information presents the condensed combined results of operations of Delek and Alon for the nine months ended September 30, 2017 as if the Delek/Alon Merger had occurred on January 1, 2017, and reflects the final purchase price allocation. The unaudited pro forma financial information is not intended to represent or be indicative of the consolidated results of operations that would have been reported had the Delek/Alon merger been completed as of January 1, 2017, and should not be taken as indicative of New Delek's future consolidated results of operations. In addition, the unaudited pro forma condensed combined results of operations do not reflect any cost savings or associated costs to achieve such savings from operating efficiencies, synergies, debt refinancing or other restructuring that may result from the Delek/Alon Merger. The pro forma financial information also does not reflect certain non-recurring adjustments that have been or are expected to be recorded in connection with the Delek/Alon Merger, including any accrual for integration costs or transaction costs or additional transactions costs related to the Merger, nor any retrospective adjustments related to the conforming of Alon's accounting policies to Delek's accounting policies, as such adjustments are impracticable to determine, and such adjustments are not expected to be indicative of on-going operations of the combined company. Finally, the pro forma presentation of net revenues and net income is inclusive of the revenue and net income (loss) attributable to the California Discontinued Entities (which are generally not material as the majority of the California Discontinued Entities were non-operating during the pro forma period). Pro forma adjustments are tax-effected at the Company's estimated statutory tax rates.



(in millions, except per share data)	Nine Months Ended September 30, 2017⁽¹⁾
Net revenues	$	6,994.1
Net income attributable to Delek	$	3.5
Earnings per share:
Basic	$	0.04
Diluted	$	0.04

⁽¹⁾The pro forma information for the nine months ended September 30, 2017 presented in our September 30, 2017 Quarterly Report on Form 10-Q has been updated to reflect the final purchase price allocation in the table above.

The unaudited pro forma statements of operations reflect the following adjustments:


•	To eliminate transactions between Delek and Alon for purchases and sales of refined products, reducing revenue and the associated cost of materials and other. Such pro forma eliminations resulted in a decrease to combined pro forma revenue by $59.0 million for the nine months ended September 30, 2017.


•	To eliminate the non-recurring transaction costs incurred during the historical periods. Such adjustments to general and administrative expense have been estimated to result in an increase to pro forma pre-tax income attributable to Delek totaling $11.5 million for the nine months ended September 30, 2017.

•

To retrospectively reflect depreciation of property, plant and equipment and amortization of intangibles based on the fair value of the assets as of the acquisition date, as if that fair value had been reflected beginning January 1, 2017, and to retrospectively eliminate the amortization of any previously recorded intangibles. Such adjustments to depreciation and amortization have been estimated to result in an increase to pro forma pre-tax income attributable to Delek totaling $34.7 million for the nine months months ended September 30, 2017.


•	To retrospectively reflect the accretion of asset retirement obligations and certain environmental liabilities. Such adjustments to general and administrative expense have been estimated to result in a decrease to pro forma pre-tax income attributable to Delek totaling $0.8 million for the nine months ended September 30, 2017.

Notes to Condensed Consolidated Financial Statements (Unaudited)

•

To retrospectively reflect adjustments to interest expense, including the impact of discounts or premiums created by the difference in fair value and outstanding amounts as of the acquisition date (collectively, the “new effective yield”), by applying the new effective yield to historical outstanding amounts in the pro forma period and reversing previously recognized interest expense. Such net adjustments to interest expense have been estimated to result in an increase to pro forma pre-tax income attributable to Delek totaling $9.4 million for the nine months ended September 30, 2017.


•	To eliminate Delek’s equity income previously recorded on its equity method investment in Alon, prior to the Merger. Such pro forma elimination resulted in a decrease to pro forma pre-tax income attributable to Delek totaling $3.2 million for the nine months ended September 30, 2017.


•	To eliminate the gain on remeasurement of the equity method investment in Alon totaling $190.1 million during the nine months ended September 30, 2017.


•	To record the tax effect on pro forma adjustments and additional tax benefit associated with dividends received from Alon at a combined U.S. (federal and state) income tax statutory blended rate of approximately 37% for both the nine months ended September 30, 2017.

•

To adjust the weighted average number of shares outstanding based on 0.504 of a share of Delek common stock for each share of Alon common stock outstanding as of July 1, 2017, as if they were outstanding for the entire nine months ended September 30, 2017, reflecting the elimination of Alon historical weighted average shares outstanding and the addition of the estimated New Delek incremental shares issued.

Delek began consolidating Alon's results of operations on July 1, 2017. Alon operations contributed $521.0 million and $2,262.3 million to net revenues and $153.0 million and $210.3 million to pre-tax income for the three and nine months ended September 30, 2018, respectively, inclusive of the contribution of the California Discontinued Entities. Alon operations contributed $1,008.8 million to net revenues and and $33.4 million to pre-tax income for the three and nine months ended September 30, 2017, inclusive of the contribution of the California Discontinued Entities.

Updates to the Preliminary Purchase Price Allocation

During the nine months ended September 30, 2018, we finalized our procedures to determine the fair value of assets acquired and liabilities assumed in the Delek/Alon Merger, as anticipated and disclosed in our 2017 Annual Report on Form 10-K (all of which were completed by June 30, 2018). As a result, the following changes were made to the preliminary purchase price allocation disclosed in our Annual Report on Form 10-K:



Subsequent increases (decreases) to initial allocation of fair value of net assets acquired:
Receivables ⁽¹⁾	$	10.7
Inventories	(0.5		)
Prepaids and other current assets ⁽²⁾	9.7
Property, plant and equipment	(0.2		)
Acquired intangible assets ⁽³⁾	7.7
Accounts payable ⁽⁴⁾	6.0
Obligation under Supply & Offtake Agreements ⁽⁵⁾	10.9
Current portion of environmental liabilities	0.4
Other current liabilities ⁽⁶⁾	22.3
Environmental liabilities and asset retirement obligations, net of current portion ⁽⁷⁾	65.3
Deferred income taxes ⁽⁸⁾	(8.4		)
Other non-current liabilities ⁽⁹⁾	(2.8		)
Resulting increase to goodwill	$	66.3

⁽¹⁾Change primarily relates to the recognition of a receivable associated with a third-party indemnification agreement for asset retirement obligations for one of the acquired refineries that was previously under review, and finalization of an accrued receivable estimate.

⁽²⁾Change primarily relates to a reclassification of Renewable Identification Numbers ("RINs") assets from other current liabilities to other current assets.

⁽³⁾Change is primarily due to the addition of an intangible asset for certain below-market leases that had previously been identified but for which the evaluation and determination of fair value was not complete at December 31, 2017.

⁽⁴⁾Change is primarily due to the elimination of amounts in accounts payable in the retail segment that were determined not to have value combined with reclassifications of amounts to accounts receivable.

⁽⁵⁾Change relates to true-up of certain accounts related to one of the acquired supply and offtake agreements for contractual terms that were previously under review.

Notes to Condensed Consolidated Financial Statements (Unaudited)

⁽⁶⁾Change is primarily due to an increase related to the reclassification of RINs assets from other current liabilities to other current assets and an increase related to the accrual of certain executive bonuses that were required under existing Alon employment agreements and related to service provided prior to the Delek/Alon Merger, net of adjustments to current income taxes payable to true up income taxes related to the acquired net assets.

⁽⁷⁾Change is to record the long-term portion of additional asset retirement obligations and environmental liabilities identified and/or to update preliminary estimates based on additional information.

⁽⁸⁾Change is related to adjustments to net deferred tax liabilities based on the updated purchase price allocation and revisions of preliminary tax estimates.

⁽⁹⁾Change is related to the reversal of an accrual established in the purchase price allocation related to a pre-acquisition legal contingency that was resolved during the first quarter 2018 in our favor.

During the nine months ended September 30, 2018, certain immaterial catch-up adjustments were recorded related to accretion of environmental liabilities and amortization of leasehold intangibles identified and valued during the final months of the measurement period.

Note 3 - Delek Logistics and the Alon Partnership

Delek Logistics

Delek Logistics is a publicly traded limited partnership that was formed by Delek in 2012 to own, operate, acquire and construct crude oil and refined products logistics and marketing assets. A substantial majority of Delek Logistics' assets are integral to Delek’s refining and marketing operations. As of September 30, 2018, we owned a 61.4% limited partner interest in Delek Logistics, consisting of 15,294,046 common units, and a 94.6% interest in Delek Logistics GP, LLC, which owns the entire 2.0% general partner interest, consisting of 497,861 general partner units, in Delek Logistics and all of the incentive distribution rights.

The limited partner interests in Delek Logistics not owned by us are reflected in net income attributable to non-controlling interest in the accompanying condensed consolidated statements of income and in non-controlling interest in subsidiaries in the accompanying condensed consolidated balance sheets.

In March 2018, a subsidiary of Delek Logistics completed the acquisition from a subsidiary of Delek ( the Alon Partnership) of storage tanks and terminals that support our Big Spring, Texas refinery (the "Big Spring Logistic Assets Acquisition"), which included the execution of related commercial agreements. In addition, a new marketing agreement was entered into between the subsidiary of Delek Logistics and the Alon Partnership pursuant to which the subsidiary of Delek Logistics will provide marketing services for product sales from Big Spring. The cash paid for the transferred assets was $170.8 million, subject to certain post-closing adjustments, and the cash paid for the marketing agreement was $144.2 million. The transactions were financed with borrowings under the DKL Credit Facility (as defined in Note 8 of the condensed consolidated financial statements in Item 1, Financial Statements). Prior periods have not been recast in our Segment Data Note 14, as these assets did not constitute a business in accordance with the Accounting Standard Update, "Clarifying the Definition of a Business" and were accounted for as acquisitions of assets between entities under common control.

We have agreements with Delek Logistics that, among other things, establish fees for certain administrative and operational services provided by us and our subsidiaries to Delek Logistics, provide certain indemnification obligations and establish terms for fee-based commercial logistics and marketing services provided by Delek Logistics and its subsidiaries to us, including new agreements related to the Big Spring Logistic Assets Acquisition. The revenues and expenses associated with these agreements are eliminated in consolidation.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Delek Logistics is a variable interest entity, as defined under GAAP, and is consolidated into our condensed consolidated financial statements, representing our logistics segment. With the exception of intercompany balances and the marketing agreement intangible asset and Delek's related deferred revenue which are eliminated in consolidation, the Delek Logistics condensed consolidated balance sheets as of September 30, 2018 and December 31, 2017, as presented below, are included in the consolidated balance sheets of Delek (unaudited, in millions).



	September 30, 2018			December 31, 2017
	September 30, 2018			December 31, 2017
ASSETS
Cash and cash equivalents	$	19.0		$	4.7
Accounts receivable	21.8			23.0
Accounts receivable from related parties	51.2			1.1
Inventory	4.2			20.9
Other current assets	0.4			0.7
Property, plant and equipment, net	314.7			255.1
Equity method investments	105.2			106.5
Goodwill	12.2			12.2
Intangible assets, net	155.9			15.9
Other non-current assets	9.0			3.4
Total assets	$	693.6		$	443.5
LIABILITIES AND DEFICIT
Accounts payable	$	11.5		$	19.1
Accrued expenses and other current liabilities	14.7			12.6
Long-term debt	776.7			422.6
Asset retirement obligations	5.1			4.1
Other non-current liabilities	16.0			14.3
Deficit	(130.4		)	(29.2		)
Total liabilities and deficit	$	693.6		$	443.5

Alon Partnership

The Alon Partnership owns the assets and conducts the operations of the Big Spring refinery and the associated integrated wholesale marketing operations. On November 8, 2017, Delek and the Alon Partnership entered into a definitive merger agreement under which Delek agreed to acquire all of the outstanding limited partner units which Delek did not already own in an all-equity transaction (the "Alon Partnership Merger"). This transaction closed on February 7, 2018 (the "Merger Date"). Delek owned approximately 51.0 million limited partner units of the Alon Partnership, or approximately 81.6% of the outstanding units, immediately prior to the Merger Date. Under terms of the merger agreement, the owners of the remaining outstanding units in the Alon Partnership that Delek did not own immediately prior to the Merger Date received a fixed exchange ratio of 0.49 shares of New Delek common stock for each limited partner unit of the Alon Partnership, resulting in the issuance of approximately 5.6 million shares of New Delek common stock to the public unitholders of the Alon Partnership. Because the transaction represented a combination of ownership interests under common control, the transfer of equity from non-controlling interest to owned interest (additional paid-in capital) was recorded at carrying value and no gain or loss was recognized in connection with the transaction. Additionally, book-tax basis difference was created as a result of the transaction that resulted in a deferred tax asset of approximately $13.5 million, net of a valuation allowance on certain state income tax components, that also increased additional paid-in capital.

The limited partner interests of the Alon Partnership prior to this acquisition were represented as common units outstanding. As of December 31, 2017, the 11,492,800 common units held by the public represented approximately 18.4% of the Alon Partnership’s common units outstanding. Alon USA Partners GP, LLC (the “Alon General Partner”), our wholly-owned subsidiary, owns 100% of the general partner interest in the Alon Partnership, which is a non-economic interest.

The limited partner interests in the Alon Partnership not owned by us as of December 31, 2017 are reflected in non-controlling interest in subsidiaries in the accompanying condensed consolidated balance sheet.

Prior to the Alon Partnership Merger, we had agreements with the Alon Partnership, under which the Alon Partnership agreed to reimburse us for certain administrative and operational services provided by us and our subsidiaries to the Alon Partnership, indemnify us with respect to certain matters and establish terms for the supply of products by the Alon Partnership to us.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Prior to the Merger Date, the Alon Partnership was a variable interest entity, as defined under GAAP, and was consolidated into our condensed consolidated financial statements as part of the refining segment. We have elected to push down purchase accounting to the Alon Partnership, which resulted in the push-down of the preliminary fair value of equity as purchase price consideration based on the market value of the Alon Partnership units as of the Merger Date, and the fair valuing of assets and liabilities as of the Merger Date. Such push-down purchase accounting also resulted in a determination of the fair value of our non-controlling interest in the Alon Partnership, which was estimated to be $120.6 million. With the exception of intercompany balances, which are eliminated in consolidation, the Alon Partnership condensed consolidated balance sheet as of December 31, 2017 (required disclosure for a consolidated variable interest entity), as presented below, is included in the consolidated balance sheet of Delek (unaudited, in millions).



	December 31, 2017
	December 31, 2017
ASSETS
Cash and cash equivalents	$	252.8
Accounts receivable	96.7
Accounts receivable from related parties	640.0
Inventories	133.2
Prepaid expenses and other current assets	5.9
Property, plant and equipment, net	413.3
Goodwill	576.6
Other non-current assets	59.2
Total assets	$	2,177.7
LIABILITIES AND EQUITY
Accounts payable	$	44.5
Accounts payable to related parties	794.2
Accrued expenses and other current liabilities	161.9
Current portion of long-term debt	337.4
Obligation under Supply and Offtake Agreement	120.1
Deferred income tax liability	1.3
Other non-current liabilities	34.5
Equity	683.8
Total liabilities and equity	$	2,177.7

Transaction costs incurred by the Company in connection with the Alon Partnership Merger totaled approximately $3.0 million for the nine months ended September 30, 2018. Such costs were included in general and administrative expenses in the accompanying condensed consolidated statements of income.

As of September 30, 2018, the Alon Partnership is included in Delek's condensed consolidated balance sheet as a wholly-owned subsidiary.

Note 4 - Equity Method Investments

On May 14, 2015, Delek acquired from Alon Israel Oil Company, Ltd. ("Alon Israel") approximately 33.7 million shares of common stock (the "ALJ Shares") of Alon pursuant to the terms of a stock purchase agreement with Alon Israel dated April 14, 2015 (the "Alon Acquisition"). The ALJ Shares represented an equity interest in Alon of approximately 48% at the time of acquisition. Effective July 1, 2017, Alon became a wholly-owned subsidiary of New Delek in connection with the Delek/Alon Merger. See Note 2 for further discussion.

Below are the summarized results of operations of Alon (in millions) for the nine months ended September 30, 2017, inclusive of the period through June 30, 2017 during which time Alon was accounted for as an equity method investment:



Income Statement Information	Nine Months Ended September 30, 2017
Revenue	$	2,269.7
Gross profit	351.2
Pre-tax income	20.0
Net income	15.0
Net income attributable to Alon	9.5

Notes to Condensed Consolidated Financial Statements (Unaudited)

Delek Logistics has two joint ventures that own and operate logistics assets, and which serve third parties and subsidiaries of Delek. As of September 30, 2018 and December 31, 2017, Delek Logistics' investment balance in these joint ventures was $105.2 million and $106.5 million, respectively, and was accounted for using the equity method.

In July 2017, Delek Renewables, LLC invested in a joint venture with an unrelated third party that was formed to plan, develop, construct, own, operate and maintain a terminal consisting of an ethanol unit train facility with an ethanol tank in North Little Rock, Arkansas. This investment was financed through cash from operations. As of both September 30, 2018 and December 31, 2017, Delek Renewables, LLC's investment balance in this joint venture was $2.1 million and was accounted for using the equity method. The investment in this joint venture is reflected in the refining segment.

Effective with the Delek/Alon Merger, we acquired a 50% interest in two joint ventures that own asphalt terminals located in Fernley, Nevada, and Brownwood, Texas. On May 21, 2018, Delek sold its 50% interest in the asphalt terminal located in Fernley, Nevada (see Note 5 for further discussion). As of September 30, 2018, Delek's investment balance in the Brownwood, Texas joint venture was $24.0 million and as of December 31, 2017, Delek's investment balance in both joint ventures was $29.4 million. These investments are accounted for using the equity method and are included as part of total assets in the corporate, other and eliminations segment.

Note 5. Discontinued Operations and Assets Held for Sale

California Discontinued Entities

During the third quarter 2017, we committed to a plan to sell certain assets associated with our Paramount and Long Beach, California refineries and our California renewable fuels facility (AltAir), which were acquired as part of the Delek/Alon Merger. As a result of this decision and commitment to a plan, and because it was made within three months of the Delek/Alon Merger, we met the requirements under ASC 205-20 and ASC 360 to report the results of the California Discontinued Entities as discontinued operations and to classify the California Discontinued Entities as a group of assets held for sale as of July 1, 2017. The property, plant and equipment of the California Discontinued Entities were recorded at fair value as part of the Delek/Alon Merger, and we have not recorded any depreciation of these assets since the Delek/Alon Merger.

On March 16, 2018, Delek sold to World Energy, LLC (i) all of Delek’s membership interests in AltAir (ii) certain refining assets and other related assets located in Paramount, California and (iii) certain associated tank farm and pipeline assets and other related assets located in California. Upon final settlement, Delek expects to receive net cash proceeds of approximately $85.9 million, subject to a post-closing working capital settlement, Delek’s portion of the expected biodiesel tax credit for 2017 and certain customary adjustments. The sale resulted in a loss on sale of discontinued operations totaling approximately $41.2 million during the nine months ended September 30, 2018 (none during the three months ended September 30, 2018). Of the total expected proceeds, $70.4 million was received during the nine months ended September 30, 2018 ($14.9 million of which were included in net cash flows from investing activities in discontinued operations), with the remainder expected to be collected upon final settlement. In connection with the sale, the remaining assets and liabilities associated with the sold operations that were not included in the assets and liabilities acquired/assumed by the buyer were reclassified into assets and liabilities held and used (relating to continuing operations) and are presented as such in our September 30, 2018 balance sheet.

The transaction to dispose of certain assets and liabilities associated with our Long Beach, California refinery to Bridge Point Long Beach, LLC closed July 17, 2018 resulting in initial cash proceeds of approximately $14.5 million, net of expenses, and resulting in a gain on sale of discontinued operations of approximately $1.4 million during the three and nine months ended September 30, 2018.

The carrying amount of the major classes of assets and liabilities of the California Discontinued Entities included in assets held for sale and liabilities associated with assets held for sale are as follows (in millions):



	December 31, 2017
Assets held for sale:
Cash and cash equivalents	$	10.1
Accounts receivable	7.9
Inventory	1.9
Other current assets	1.3
Property, plant & equipment, net	130.0
Other intangibles, net	6.6
Other non-current assets	2.2
Assets held for sale	$	160.0
Liabilities associated with assets held for sale:
Accrued expenses and other current liabilities	$	9.5
Deferred tax liabilities	63.9
Other non-current liabilities	32.5
Liabilities associated with assets held for sale	$	105.9

Notes to Condensed Consolidated Financial Statements (Unaudited)

Once the operating assets of the California Discontinued Entities met the criteria to be classified as assets held for sale, the operations associated with these properties qualified for reporting as discontinued operations. Accordingly, the operating results, net of tax, from discontinued operations are presented separately in Delek’s condensed consolidated statements of income and the notes to the condensed consolidated financial statements have been adjusted to exclude the discontinued operations. Classification as discontinued operations requires retrospective reclassification of the associated assets, liabilities and results of operations for all periods presented, beginning (in this case) as of the date of acquisition, which was July 1, 2017. Components of amounts reflected in income from discontinued operations are as follows (in millions):



	Three Months Ended						Nine Months Ended
	September 30, 2018			September 30, 2017			September 30, 2018			September 30, 2017
Net revenues	$	—		38.3			32.5			38.3
Cost of sales:
Cost of materials and other	—			(32.4		)	3.8			(32.4		)
Operating expenses (excluding depreciation and amortization)	(0.6		)	(8.4		)	(9.4		)	(8.4		)
Total cost of sales	(0.6		)	(40.8		)	(5.6		)	(40.8		)
General and administrative expenses	—			(2.9		)	(1.1		)	(2.9		)
Other operating income, net	—			—			0.3			—
Interest expense	—			(1.0		)	—			(1.0		)
Interest income	—			—			3.0			—
Income (loss) on sale of California Discontinued Entities	1.4			—			(39.8		)	—
income (loss) from discontinued operations before taxes	0.8			(6.4		)	(10.7		)	(6.4		)
Income tax expense (benefit)	0.3			(2.3		)	(2.2		)	(2.3		)
Income (loss) from discontinued operations, net of tax	$	0.5		$	(4.1	)	$	(8.5	)	$	(4.1	)

The net assets of the California Discontinued Entities include a non-controlling interest totaling $10.5 million as of December 31, 2017, related to AltAir. Net income attributable to non-controlling interest included $8.1 million related to AltAir for the nine months ended September 30, 2018 (none for the three months ended September 30, 2018).

Asphalt Terminals Held for Sale

On February 12, 2018, Delek announced it had reached a definitive agreement to sell certain assets and operations of four asphalt terminals (included in Delek's corporate/other segment), as well as an equity method investment in an additional asphalt terminal, to an affiliate of Andeavor. This transaction includes asphalt terminal assets in Bakersfield, Mojave and Elk Grove, California and Phoenix, Arizona, as well as Delek’s 50 percent equity interest in the Paramount-Nevada Asphalt Company, LLC joint venture that operates an asphalt terminal located in Fernley, Nevada. On May 21, 2018, Delek completed the transaction and received net proceeds of approximately $110.8 million, inclusive of the $75.0 million base proceeds as well as certain preliminary working capital adjustments. The assets associated with the owned terminals met the definition of held for sale pursuant to ASC 360 as of February 1, 2018, but did not meet the definition of discontinued operations pursuant to ASC 205-20, as the sale of these asphalt assets does not represent a strategic shift that will have a major effect on the entity's operations and financial results. Accordingly, depreciation ceased as of February 1, 2018, and the assets to be sold were reclassified to assets held for sale as of that date and were written down to the estimated fair value less costs to sell, resulting in an impairment loss on assets held for sale of $27.5 million for the nine months ended September 30, 2018 (none for the three months ended September 30, 2018). All goodwill associated with the asphalt operations sold was written off in connection with the impairment charge discussed above. In connection with the completion of the sale transaction, we recognized a gain of approximately $13.2 million, resulting primarily from the recognition of certain additional proceeds at closing associated with the asphalt terminals which were not previously determinable/probable and the recognition of the gain on the sale of the joint venture which was not previously recognized as held for sale (as it did not meet the criteria). Such gain on sale of the asphalt assets is reflected in results of continuing operations on the accompanying consolidated income statement.

These associated assets did not meet the definition of held for sale pursuant to ASC 360 as of December 31, 2017, and therefore were not reflected as held for sale nor as discontinued operations in the consolidated financial statements as of and for the year ended December 31, 2017.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 6 - Inventory

Crude oil, work in process, refined products, blendstocks and asphalt inventory for all of our operations, excluding the Tyler, Texas refinery (the "Tyler refinery") and merchandise inventory in our retail segment, are stated at the lower of cost determined using the FIFO basis or net realizable value. Cost of all inventory at the Tyler refinery is determined using the LIFO inventory valuation method and inventory is stated at the lower of cost or market. Retail merchandise inventory consists of cigarettes, beer, convenience merchandise and food service merchandise and is stated at estimated cost as determined by the retail inventory method.

Carrying value of inventories consisted of the following (in millions):



	September 30, 2018		December 31, 2017
Refinery raw materials and supplies	$	443.1	$	308.0
Refinery work in process	126.3		79.2
Refinery finished goods	312.1		366.4
Retail fuel	12.3		8.3
Retail merchandise	25.9		25.6
Logistics refined products	4.2		20.9
Total inventories	$	923.9	$	808.4

At September 30, 2018, we recorded a pre-tax inventory valuation reserve of $0.6 million, $0.6 million of which related to LIFO inventory due to a market price decline below our average cost of certain inventory products, which is subject to reversal in subsequent periods, not to exceed LIFO cost, should market prices recover. At December 31, 2017, we recorded a pre-tax inventory valuation reserve of $2.4 million, $1.5 million of which related to LIFO inventory, which reversed in the first quarter of 2018, as the inventories associated with the valuation adjustment at the end of 2017 were sold or used. We recognized gains (losses) related to pre-tax inventory valuation of $0.1 million and $1.8 million for the three and nine months ended September 30, 2018, respectively, and $12.0 million and $(1.5) million for the three and nine months ended September 30, 2017, respectively. These gains (losses) were recorded as a component of cost of materials and other in the accompanying condensed consolidated statements of income.

Permanent Liquidations

We incurred a reduction in a LIFO layer resulting in liquidation (loss) gain in our refinery inventory of $(0.1) million and $(0.3) million during the three and nine months ended September 30, 2018, respectively, and $0.4 million and $0.2 million during the three and nine months ended September 30, 2017, respectively. These liquidation (losses) gains were recognized as a component of cost of materials and other in the accompanying condensed consolidated statements of income. Such liquidations become permanent to the extent that they do not reverse at the end of our annual period.

Note 7 - Crude Oil Supply and Inventory Purchase Agreements

Delek has Master Supply and Offtake Agreements (the "Supply and Offtake Agreements") with J. Aron & Company ("J. Aron").

El Dorado refinery operations

Throughout the term of the Supply and Offtake Agreement that supports the operations of our refinery located in El Dorado, Arkansas (the "El Dorado Supply and Offtake Agreement"), which was amended on February 27, 2017 to change, among other things, certain terms related to pricing and an extension of the maturity date to April 30, 2020, Lion Oil Company ("Lion Oil") (as the primary legal entity associated with the El Dorado refinery for purposes of this Agreement) and J. Aron will identify mutually acceptable contracts for the purchase of crude oil from third parties and J. Aron will supply up to 100,000 bpd of crude oil to the El Dorado refinery. Crude oil supplied to the El Dorado refinery by J. Aron will be purchased daily at an estimated average monthly market price by Lion Oil. J. Aron will also purchase all refined products from the El Dorado refinery at an estimated daily market price, as they are produced. These daily purchases and sales are trued-up on a monthly basis in order to reflect actual average monthly prices. We have recorded a receivable related to this monthly settlement of $11.9 million and $0.3 million as of September 30, 2018 and December 31, 2017, respectively. Also pursuant to the El Dorado Supply and Offtake Agreement and other related agreements, Lion Oil will endeavor to arrange potential sales by either Lion Oil or J. Aron to third parties of the products produced at the El Dorado refinery or purchased from third parties. In instances where Lion Oil is the seller to such third parties, J. Aron will first transfer title to the applicable products to Lion Oil.

This arrangement is accounted for as a product financing arrangement. Delek incurred fees payable to J. Aron under the El Dorado Supply and Offtake Agreement of $2.7 million and $8.3 million during the three and nine months ended September 30, 2018, respectively, and $2.5 million and $7.3 million during the three and nine months ended September 30, 2017, respectively. These amounts are included as a component of interest expense in the condensed consolidated statements of income. Upon any termination of the El Dorado Supply and Offtake Agreement, including in connection with a force majeure event, the parties are required to negotiate with third parties for the assignment to us of certain contracts, commitments and arrangements, including procurement contracts, commitments for the sale of product, and pipeline, terminalling, storage and shipping arrangements.

Upon the expiration of the El Dorado Supply and Offtake Agreement on April 30, 2020, or upon any earlier termination, Delek will be required to repurchase the consigned crude oil and refined products from J. Aron at then prevailing market prices. At September 30, 2018 and December 31, 2017, Delek had 3.0 million barrels and 3.0 million barrels, respectively, of inventory consigned from J. Aron under the El Dorado Supply and Offtake Agreement, and we have recorded liabilities associated with this consigned inventory of $204.2 million and $181.9 million, respectively, in the condensed consolidated balance sheets.

Alon refinery operations

Effective with the Delek/Alon Merger, we assumed Alon's existing Supply and Offtake Agreements and other associated agreements with J. Aron to support the operations of our Big Spring, Krotz Springs and California refineries (as further defined in Note 14) and certain of our asphalt terminals (together, the “Alon Supply and Offtake Agreements”). Pursuant to the Alon Supply and Offtake Agreements, (i) J. Aron agreed to sell to us, and we agreed to buy from J. Aron, at market prices, crude oil for processing at these refineries and (ii) we agreed to sell, and J. Aron agreed to buy, at market prices, certain refined products produced at these refineries. The Alon Supply and Offtake Agreements also provide for the sale, at market prices, of our crude oil and certain refined product inventories to J. Aron, the lease to J. Aron of crude oil and refined product storage facilities and the identification of prospective purchasers of refined products on J. Aron’s behalf. The Supply and Offtake Agreements for the Big Spring and Krotz Springs refineries have initial terms that expire in May 2021. The Supply and Offtake Agreement for the California refineries, which had an initial expiration date in May 2019, contained early termination provisions, and we elected to terminate the Supply and Offtake Agreement at the California refineries effective on May 31, 2018. J. Aron may elect to terminate the Supply and Offtake Agreements for the Big Spring and Krotz Springs refineries prior to the expiration of the initial term beginning in May 2019 and upon each anniversary thereafter, on six months' prior notice. We may elect to terminate the agreements at the Big Spring and Krotz Springs refineries in May 2020 on six months' prior notice.

These daily purchases and sales are trued-up on a monthly basis in order to reflect actual average monthly prices. We have recorded a net payable related to this monthly settlement of $(0.3) million and $(4.4) million as of September 30, 2018 and December 31, 2017, respectively.

These arrangements are accounted for as product financing arrangements. Delek incurred fees payable to J. Aron of $3.6 million and $10.4 million during the three and nine months ended September 30, 2018, respectively, and $2.3 million during the three months ended September 30, 2017. These amounts are included as a component of interest expense in the condensed consolidated statements of income. Upon any termination of the Alon Supply and Offtake Agreements, including in connection with a force majeure event, the parties are required to negotiate with third parties for the assignment to us of certain contracts, commitments and arrangements, including procurement contracts, commitments for the sale of product, and pipeline, terminalling, storage and shipping arrangements.

Upon the expiration of the Alon Supply and Offtake Agreements, or upon any earlier termination, Delek will be required to repurchase the consigned crude oil and refined products from J. Aron at then prevailing market prices. At September 30, 2018 and December 31, 2017, Delek had 3.3 million barrels and 3.5 million barrels, respectively, of inventory consigned from J. Aron under the Alon Supply and Offtake Agreements, and we have recorded liabilities associated with this consigned inventory of $274.5 million and $253.7 million, respectively, in the condensed consolidated balance sheets.

In connection with the Alon Supply and Offtake Agreement for our Krotz Springs refinery, we have granted a security interest to J. Aron in certain assets (including all of its accounts receivable and inventory) to secure its obligations to J. Aron.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 8 - Long-Term Obligations and Notes Payable

Outstanding borrowings, net of unamortized debt discounts and certain deferred financing costs, under Delek’s existing debt instruments are as follows (in millions):



	September 30, 2018		December 31, 2017
Revolving Credit Facility	$	300.0	$	—
Term LoanCredit Facility ⁽¹⁾	685.3		—
DKL Credit Facility	533.2		179.9
DKL Notes ⁽²⁾	243.5		242.7
Convertible Notes ⁽³⁾	—		146.0
Reliant Bank Revolver	30.0		17.0
Promissory Notes	70.0		95.1
Wells Term Loan ⁽⁴⁾	—		40.5
Wells Revolving Loan	—		45.0
Lion Term Loan Facility ⁽⁵⁾	—		203.4
Alon Partnership Credit Facility	—		100.0
Alon Partnership Term Loan	—		237.5
Alon Term Loan Credit Facilities⁽⁶⁾	—		72.4
Alon Retail Credit Facilities ⁽⁷⁾	—		86.1
	1,862.0		1,465.6
Less: Current portion of long-term debt and notes payable	32.0		590.2
	$	1,830.0	$	875.4


⁽¹⁾	The Term Loan Credit Facility is net of deferred financing costs of $2.5 million and debt discount of $8.7 million at September 30, 2018.


⁽²⁾	The DKL Notes are net of deferred financing costs of $4.9 million and $5.6 million, respectively, and debt discount of $1.6 million and $1.7 million, respectively, at September 30, 2018 and December 31, 2017.


⁽³⁾	The Convertible Notes were extinguished on September 17, 2018, as further discussed below, and were net of debt discount of $4.0 million at December 31, 2017.


⁽⁴⁾	The Wells Term Loan was extinguished on March 30, 2018, as further discussed below, and was net of deferred financing costs of a nominal amount and debt discount $0.3 million at December 31, 2017.


⁽⁵⁾	The Lion Term Loan Facility was extinguished on March 30, 2018, as further discussed below, and was net of deferred financing costs of $2.1 million and debt discount of $0.8 million at December 31, 2017.


⁽⁶⁾	The Alon Term Loan Credit Facilities were extinguished on March 30, 2018, as further discussed below, and were net of debt discount of $0.6 million at December 31, 2017.


⁽⁷⁾	The Alon Retail Credit Facilities were extinguished on March 30, 2018, as further discussed below, and were net of debt discount of $2.4 million at December 31, 2017.

Delek Revolver and Term Loan

The Revolving Credit Facility permits borrowings in Canadian dollars of up to $50.0 million. The Revolving Credit Facility also permits the issuance of letters of credit of up to $300.0 million, including letters of credit denominated in Canadian dollars of up to $10.0 million. Delek may designate restricted subsidiaries as additional borrowers under the Revolving Credit Facility.

The Term Loan Credit Facility was drawn in full for $700.0 million on the Closing Date at an original issue discount of 0.50%. Proceeds under the Term Loan Credit Facility, as well as proceeds of approximately $300.0 million in borrowings under the Revolving Credit Facility on the Closing Date, were used to repay certain indebtedness of Delek and its subsidiaries (the “Refinancing”), as well as certain fees, costs and expenses in connection with the closing of the New Credit Facilities, with any remaining proceeds held in cash. Proceeds of future borrowings under the Revolving Credit Facility will be used for working capital and general corporate purposes of Delek and its subsidiaries.

Notes to Condensed Consolidated Financial Statements (Unaudited)

We recorded a loss on extinguishment of debt totaling approximately $9.1 million during the nine months ended September 30, 2018 in connection with the Refinancing.

Interest and Unused Line Fees

The interest rates applicable to borrowings under the Term Loan Credit Facility and the Revolving Credit Facility are based on a fluctuating rate of interest measured by reference to either, at Delek’s option, (i) a base rate, plus an applicable margin, or (ii) a reserve-adjusted London Interbank Offered Rate ("LIBOR"), plus an applicable margin (or, in the case of Revolving Credit Facility borrowings denominated in Canadian dollars, the Canadian dollar bankers' acceptances rate ("CDOR")). The initial applicable margin for all Term Loan Credit Facility borrowings was 1.50% per annum with respect to base rate borrowings and 2.50% per annum with respect to LIBOR borrowings.

On October 26, 2018, Delek entered into an amendment to the Term Loan Credit Facility (the “First Amendment”) to reduce the margin on certain borrowings under the Term Loan Credit Facility and incorporate certain other changes. The First Amendment prospectively decreases the applicable margins for borrowings under (i) Base Rate Loans from 1.50% to 1.25% and (ii) LIBOR Rate Loans from 2.50% to 2.25%, as such terms are defined in the Term Loan Credit Facility. The decreases to the applicable margins became effective upon execution of the First Amendment.

The initial applicable margin for Revolving Credit Facility borrowings was 0.25% per annum with respect to base rate borrowings and 1.25% per annum with respect to LIBOR and CDOR borrowings, and the applicable margin for such borrowings after September 30, 2018 is based on Delek’s excess availability as determined by reference to a borrowing base, ranging from 0.25% to 0.75% per annum with respect to base rate borrowings and from 1.25% to 1.75% per annum with respect to LIBOR and CDOR borrowings.

In addition, the Revolving Credit Facility will require Delek to pay an unused line fee on the average amount of unused commitments thereunder in each quarter, which fee will be at a rate of 0.250% or 0.375% per annum, depending on average commitment usage for such quarter. The initial unused line fee is set at 0.375% per annum through September 30, 2018.

Maturity and Repayments

The Revolving Credit Facility will mature and the commitments thereunder will terminate on March 30, 2023. The Term Loan Credit Facility requires scheduled quarterly principal payments of $1.75 million, with the balance of the principal due on March 30, 2025. Additionally, the Term Loan Credit Facility requires prepayments by Delek with the net cash proceeds from certain debt incurrences, asset dispositions and insurance or condemnation events with respect to Delek’s assets, subject to certain exceptions, thresholds and reinvestment rights. The Term Loan Credit Facility also requires prepayments with a variable percentage of Delek’s excess cash flow, ranging from 50% to 0% depending on Delek’s consolidated secured net leverage ratio from time to time. Delek may also make voluntarily prepayments under the Term Loan Credit Facility at any time, subject to a prepayment premium of 1.00% in connection with certain customary repricing events that may occur within six months after the Closing Date, with no premium applied after six months.

Guarantee and Security

The obligations of the borrowers under the New Credit Facilities are guaranteed by Delek and each of its direct and indirect, existing and future, wholly-owned domestic subsidiaries, subject to customary exceptions and limitations, and excluding Delek Logistics Partners, LP, Delek Logistics GP, LLC, and each subsidiary of the foregoing (collectively, the "MLP Subsidiaries"). Borrowings under the New Credit Facilities are also guaranteed by DK Canada Energy ULC, a British Columbia unlimited liability company and a wholly-owned restricted subsidiary of Delek.

The Revolving Credit Facility is secured by a first priority lien over substantially all of Delek’s and each guarantor's receivables, inventory, renewable identification numbers, instruments, intercompany loan receivables, deposit and securities accounts and related books and records and certain other personal property, subject to certain customary exceptions (the "Revolving Priority Collateral"), and a second priority lien over substantially all of the Delek's and each guarantor's other assets, including all of the equity interests of any subsidiary held by Delek or any guarantor (other than equity interests in certain MLP Subsidiaries) subject to certain customary exceptions, but excluding real property (such real property and equity interests, the "Term Priority Collateral").

The Term Loan Credit Facility is secured by a first priority lien on the Term Priority Collateral and a second priority lien on the Revolving Priority Collateral, all in accordance with an intercreditor agreement between the Term Administrative Agent and the Revolver Administrative Agent and acknowledged by Delek and the subsidiary guarantors. Certain excluded assets are not included in the Term Priority Collateral and the Revolving Priority Collateral.

Additional Information

At September 30, 2018, the weighted average borrowing rate under the Revolving Credit Facility was 5.50% and was comprised entirely of a base rate borrowing, and the principal amount outstanding thereunder was $300.0 million. Additionally, there were letters of credit issued of approximately $143.5 million as of September 30, 2018 under the Revolving Credit Facility. Unused credit commitments under the Revolving Credit Facility, as of September 30, 2018, were approximately $556.5 million

At September 30, 2018, the weighted average borrowing rate under the Term Loan Credit Facility was approximately 4.74% comprised entirely of a LIBOR borrowing and the principal amount outstanding thereunder was approximately $696.5 million.

Notes to Condensed Consolidated Financial Statements (Unaudited)

DKL Credit Facility

At December 31, 2017, Delek Logistics had a $700.0 million senior secured revolving credit agreement with Fifth Third Bank ("Fifth Third"), as administrative agent, and a syndicate of lenders (the "2014 Facility") with a $100.0 million accordion feature, bearing interest at (i) either a U.S. prime dollar rate or a LIBOR Rate for borrowings denominated in U.S. Dollars, or (ii) either a Canadian dollar prime rate, or a Canadian Dealer Offered Rate, for borrowing denominated in Canadian dollars (in each case plus applicable margins, at the election of the borrowers and as a function of draw down currency). The 2014 Facility had a maturity date of December 30, 2019. Outstanding borrowings at December 31, 2017 were $179.9 million. The obligations under the 2014 Facility were secured by a first priority lien on substantially all of Delek Logistics' tangible and intangible assets. Additionally, a subsidiary of Delek provided a limited guaranty of Delek Logistics' obligations under the 2014 Facility.

On September 28, 2018, Delek Logistics and all of its subsidiaries entered into a third amended and restated senior secured revolving credit agreement, which amended and restated the 2014 Facility (hereafter, the "DKL Credit Facility") with Fifth Third, as administrative agent, and a syndicate of lenders. The DKL Credit Facility contains a dual currency borrowing tranche that permits draw downs in U.S. or Canadian dollars. Under the terms of the DKL Credit Facility, among other things, the lender commitments were increased from $700.0 million to $850.0 million. The DKL Credit Facility also contains an accordion feature whereby the Partnership can increase the size of the credit facility to an aggregate of $1.0 billion, subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent.

The obligations under the DKL Credit Facility remain secured by first priority liens on substantially all of Delek Logistics' tangible and intangible assets. Additionally, a subsidiary of Delek continues to provide a limited guaranty of Delek Logistics' obligations under the DKL Credit Facility. The guaranty is (i) limited to an amount equal to the principal amount, plus unpaid and accrued interest, of a promissory note made by Delek in favor of the subsidiary guarantor (the "Holdings Note") and (ii) secured by the subsidiary guarantor's pledge of the Holdings Note to the DKL Credit Facility lenders. As of both September 30, 2018 and December 31, 2017, the principal amount of the Holdings Note was $102.0 million.

The DKL Credit Facility has a maturity date of September 28, 2023. Borrowings under the DKL Credit Facility bear interest at either a U.S. dollar prime rate, Canadian prime rate, LIBOR, or a Canadian Dealer Offered Rate, in each case plus applicable margins, at the election of the borrowers and as a function of draw down currency. The applicable margin in each case and the fee payable for the unused revolving commitments vary based upon Delek Logistics' most recent total leverage ratio calculation delivered to the lenders, as called for and defined under the terms of the DKL Credit Facility. At September 30, 2018, the weighted average borrowing rate was approximately 4.86%. Additionally, the DKL Credit Facility requires Delek Logistics to pay a leverage ratio dependent quarterly fee on the average unused revolving commitment. As of September 30, 2018, this fee was 0.40% per year.

As of September 30, 2018, Delek Logistics had $533.2 million of outstanding borrowings under the DKL Credit Facility, with no letters of credit in place. Unused credit commitments under the DKL Credit Facility, as of September 30, 2018, were $316.8 million.

DKL Notes

On May 23, 2017, Delek Logistics and Delek Logistics Finance Corp. (collectively, the “Issuers”) issued $250.0 million in aggregate principal amount of 6.75% senior notes due 2025 (the “DKL Notes”) at a discount. The DKL Notes are general unsecured senior obligations of the Issuers. The DKL Notes are unconditionally guaranteed jointly and severally on a senior unsecured basis by Delek Logistics' existing subsidiaries (other than Delek Logistics Finance Corp., the "Guarantors") and will be unconditionally guaranteed on the same basis by certain of Delek Logistics' future subsidiaries. The DKL Notes rank equal in right of payment with all existing and future senior indebtedness of the Issuers, and senior in right of payment to any future subordinated indebtedness of the Issuers. Interest on the DKL Notes is payable semi-annually in arrears on each May 15 and November 15, commencing November 15, 2017.

At any time prior to May 15, 2020, the Issuers may redeem up to 35% of the aggregate principal amount of the DKL Notes with the net cash proceeds of one or more equity offerings by Delek Logistics at a redemption price of 106.750% of the redeemed principal amount, plus accrued and unpaid interest, if any, subject to certain conditions and limitations. Prior to May 15, 2020, the Issuers may redeem all or part of the DKL Notes at a redemption price of the principal amount plus accrued and unpaid interest, if any, plus a "make whole" premium, subject to certain conditions and limitations. In addition, beginning on May 15, 2020, the Issuers may, subject to certain conditions and limitations, redeem all or part of the DKL Notes, at a redemption price of 105.063% of the redeemed principal for the twelve-month period beginning on May 15, 2020, 103.375% for the twelve-month period beginning on May 15, 2021, 101.688% for the twelve-month period beginning on May 15, 2022 and 100.00% beginning on May 15, 2023 and thereafter, plus accrued and unpaid interest, if any.

In the event of a change of control, accompanied or followed by a ratings downgrade within a certain period of time, subject to certain conditions and limitations, the Issuers will be obligated to make an offer for the purchase of the DKL Notes from holders at a price equal to 101% of the principal amount thereof, plus accrued and unpaid interest.

Notes to Condensed Consolidated Financial Statements (Unaudited)

In connection with the issuance of the DKL Notes, the Issuers and the Guarantors entered into a registration rights agreement, whereby the Issuers and the Guarantors were required to exchange the DKL Notes for new notes with terms substantially identical in all material respects with the DKL Notes (except the new notes do not contain terms with respect to transfer restrictions). On April 25, 2018, Delek Logistics made an offer to exchange the DKL Notes and the related guarantees that were validly tendered and not validly withdrawn for an equal principal amount of exchange notes that are freely tradeable, as required under the terms of the original indenture (the “Exchange Offer”). The Exchange Offer expired on May 23, 2018 (the "Expiration Date"). The terms of the exchange notes that were issued as a result of the Exchange Offer (also referred to as the "2025 Notes") are substantially identical to the terms of the original DKL Notes.

As of September 30, 2018, we had $250.0 million in outstanding principal amount under the DKL Notes.

Alon Convertible Senior Notes (share values in dollars)

In connection with the Delek/Alon Merger, Alon, New Delek and U.S. Bank National Association, as trustee (the “Trustee”) entered into a First Supplemental Indenture (the “Supplemental Indenture”), effective as of July 1, 2017, supplementing the Indenture, dated as of September 16, 2013 (the “Original Indenture” the Original Indenture, as amended by the Supplemental Indenture, is referred to as the "Indenture"), pursuant to which Alon issued its 3.00% Convertible Senior Notes due 2018 (the “ Convertible Notes”) in the aggregate principal amount of $150.0 million, which were convertible into shares of Alon’s Common Stock, par value $0.01 per share or cash or a combination of cash and Alon Common Stock, at Alon's election, all as provided in the Indenture. The Supplemental Indenture provided that, as of the Effective Time, the right to convert each $1,000 principal amount of the Notes based on a number of shares of Alon Common Stock equal to the Conversion Rate (as defined in the Indenture) in effect immediately prior to the Merger was changed into a right to convert each $1,000 principal amount of Notes into or based on a number of shares of New Delek Common Stock (at the exchange rate of 0.504), par value $0.01 per share, equal to the Conversion Rate in effect immediately prior to the Merger. In addition, the Supplemental Indenture provided that, as of the Effective Time, New Delek fully and unconditionally guaranteed, on a senior basis, Alon’s obligations under the Convertible Notes.

Interest on the Convertible Notes was payable in arrears in March and September of each year. The Convertible Notes were not redeemable at our option prior to maturity. Under the terms of the Convertible Notes, the holders of the Convertible Notes could not require us to repurchase all or part of the notes except for instances of a fundamental change, as defined in the indenture.

The holders of the Convertible Notes could convert their notes at any time after June 15, 2018 into a settlement amount determined in accordance with the terms of the Indenture. The Convertible Notes could be converted into shares of New Delek Common Stock, into cash, or into a combination of cash and shares of New Delek Common Stock, at our election. In May 2018, we made the election and notified holders of our intention to satisfy the principal amount outstanding with cash and the incremental value of the conversion options with shares at maturity.

The conversion rate of the Convertible Notes was subject to adjustment upon the occurrence of certain events, including cash dividend adjustments. On September 17, 2018, Delek settled the Convertible Notes for a combination of cash and shares of New Delek Common Stock. The maturity settlement in respect of the Convertible Notes consisted of (i) cash payments totaling approximately $152.5 million which included a cash payment for outstanding principal of $150.0 million, a cash payment for accrued interest of approximately $2.2 million, a cash payment for dividends of approximately $0.3 million and a nominal cash payment in lieu of fractional shares, and (ii) the issuance of approximately 2.7 million shares of New Delek Common Stock to holders of the Convertible Notes (the “Conversion Shares”). The issuance of the Conversion Shares was made in exchange for the Convertible Notes pursuant to an exemption from the registration requirements provided by Section 3(a)(9) of the Securities Act of 1933, as amended.

Prior to the conversion, the conversion feature met the definition for recognition as a bifurcated equity instrument. At December 31, 2017, the conversion feature equity instrument totaled $26.6 million and was included in additional paid-in capital on the accompanying condensed consolidated balance sheets.

Convertible Note Hedge Transactions

In connection with the Convertible Notes offering, Alon entered into convertible note hedge transactions with respect to Alon Common Stock (the “Call Options”) with the initial purchasers of the Convertible Notes (the “Hedge Counterparties”). In connection with the Delek/Alon Merger, Alon, Delek and the Hedge Counterparties entered into amended and restated Call Options permitting us to purchase up to approximately 5.7 million shares of New Delek Common Stock, subject to customary anti-dilution adjustments, that underlie the Convertible Notes sold in the offering.

The Call Options were intended to reduce the potential dilution with respect to our common stock upon conversion of the Convertible Notes or upon settlement of the incremental value of the conversion options associated with the Convertible Notes in shares, as well as offset any potential cash payments we would be required to make in excess of the principal amount upon any conversion of the notes. As of December 31, 2017, the Call Options totaling $23.3 million were included as a reduction of additional paid-in capital on the condensed consolidated balance sheets. The Call Options were separate transactions and were not part of the terms of the Convertible Notes and were excluded from classification as a derivative as the amount could be settled in our stock. Holders of the Convertible Notes did not have any rights with respect to the Call Options.

Notes to Condensed Consolidated Financial Statements (Unaudited)

On September 17, 2018, we exercised the Call Options in connection with the settlement of the Convertible Notes and received approximately 2.7 million shares of our common stock from the Call Option counterparties. On a net basis, the settlement of the Convertible Notes and the exercise of the Call Options resulted in no net dilution to our common stock.

Warrant Transactions

In connection with the Convertible Notes offering, Alon also entered into warrant transactions (the “Warrants”) whereby warrants to acquire Alon common stock were sold to the Hedge Counterparties. In connection with the Delek/Alon Merger, Alon, Delek and the Hedge Counterparties entered into amended and restated Warrants which allow the Hedge Counterparties to purchase up to approximately 5.7 million shares of New Delek Common Stock, subject to customary anti-dilution adjustments. As of September 30, 2018, the Warrants had an adjusted strike price of approximately $35 per share of New Delek Common Stock. The Warrants require settlement on a net-share basis and will expire in April 2019. As of both September 30, 2018 and December 31, 2017, Warrants totaling $14.3 million have been included in additional paid-in capital on the condensed consolidated balance sheets.

The Warrants are separate transactions and are not part of the terms of the Convertible Notes and are excluded from classification as a derivative as the amount could be settled in our stock. Holders of the Convertible Notes did not have any rights with respect to the Warrants.

Reliant Bank Revolver

Delek has an unsecured revolving credit agreement with Reliant Bank (the "Reliant Bank Revolver"), which was amended on June 20, 2018 to extend the maturity by two years to June 28, 2020, reduce the fixed interest rate from 5.25% to 4.75% per annum and increase the maximum borrowing amount for loans from $17.0 million to $30.0 million. The Reliant Bank Revolver requires us to pay a quarterly fee of 0.50% per year on the average available revolving commitment. As of September 30, 2018, we had $30.0 million outstanding and had no unused credit commitments under the Reliant Bank Revolver

Promissory Notes

Delek had a $50.0 million promissory note with Ergon, Inc. that required Delek to make annual amortization payments of $10.0 million each, commencing April 29, 2013, and with interest computed at a fixed rate equal to 4.0% per annum. The Ergon Note matured on April 29, 2017 and was paid in full.

On May 14, 2015, in connection with the Company’s closing of the Alon Acquisition, the Company issued the Alon Israel Note in the amount of $145.0 million, which was payable to Alon Israel. The Alon Israel Note bears interest at a fixed rate of 5.5% per annum and requires five annual principal amortization payments of $25.0 million beginning in January 2016 followed by a final principal amortization payment of $20.0 million at maturity on January 4, 2021. In October 2015, we prepaid the first annual principal amortization payment in the amount of $25.0 million, along with all interest due on the prepaid amount. On December 22, 2015, Alon Israel assigned the remaining $120.0 million of principal and all accrued interest due under the Alon Israel Note to assignees under four new notes in substantially the same form and on the same terms as the Alon Israel Note (collectively, the "Alon Successor Notes"). The $120.0 million total principal of the four Alon Successor Notes collectively require the same principal amortization payments and schedule as under the Alon Israel Note, with payments due under each Alon Successor Note commensurate to such note's pro rata share of $120.0 million in assigned principal. As of September 30, 2018, a total principal amount of $70.0 million was outstanding under the Alon Successor Notes.

As of December 31, 2017, one of our retail companies had a loan that was to mature in 2019 with an outstanding balance of $0.1 million and the interest rate was fixed at 9.70%. This loan was extinguished in connection with the Refinancing on March 30, 2018.

Restrictive Covenants

Under the terms of our Revolving Credit Facility, Term Loan Credit Facility, DKL Credit Facility, DKL Notes and Reliant Bank Revolver, we are required to comply with certain usual and customary financial and non-financial covenants. The terms and conditions of the Revolving Credit Facility include periodic compliance with a springing minimum fixed charge coverage ratio financial covenant if excess availability under the revolver borrowing base is below certain thresholds, as defined in the credit agreement. The Term Loan Credit Facility does not have any financial maintenance covenants. The Convertible Notes did not contain any maintenance financial covenants. We believe we were in compliance with all covenant requirements under each of our credit facilities as of September 30, 2018.

Certain of our debt facilities contain limitations on the incurrence of additional indebtedness, making of investments, creation of liens, dispositions and acquisitions of assets, and making of restricted payments and transactions with affiliates. Specifically, these covenants may limit the payment, in the form of cash or other assets, of dividends or other distributions, or the repurchase of shares with respect to the equity of certain of our subsidiaries. Additionally, certain of our debt facilities limit our ability to make investments, including extensions of loans or advances to, or acquisitions of equity interests in, or guarantees of obligations of, any other entities.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Obligations Extinguished in Connection with the 2018 Refinancing

Wells ABL

Our subsidiary, Delek Refining, Ltd., had an asset-based loan credit facility with Wells Fargo Bank, National Association, as administrative agent, and a syndicate of lenders, which was previously amended and restated on September 29, 2016 and on May 17, 2017 (the "Wells ABL"). This facility was amended and restated on March 30, 2018 in connection with the Refinancing. The Wells ABL consisted of (i) a $450.0 million revolving loan (the "Wells Revolving Loan"), which included a $45.0 million swing line loan sub-limit and a $200.0 million letter of credit sub-limit, (ii) a $70.0 million term loan (the "Wells Term Loan"), and (iii) an accordion feature that permitted an increase in the size of the revolving credit facility to an aggregate of $725.0 million, subject to additional lender commitments and the satisfaction of certain other conditions precedent. The Wells Revolving Loan was to mature on September 29, 2021 and the Wells Term Loan was to mature on September 29, 2019. The Wells Term Loan was subject to repayment in level principal installments of approximately $5.8 million per quarter, with the final installment due on September 29, 2019. The obligations under the Wells ABL were secured by (i) substantially all the assets of Refining and its subsidiaries, with certain limitations, (ii) guaranties provided by the general partner of Delek Refining, Ltd., as well as by the parent of Delek Refining, Ltd., Delek Refining, Inc. (iii) a limited guarantee provided jointly and severally by Old and New Delek in an amount up to $15.0 million in the aggregate and (iv) a limited guarantee provided by Lion Oil in an amount equal to the sum of the face amount of all letters of credit issued on behalf of Lion Oil under the Wells ABL and any loans made by Refining or its subsidiaries to Lion Oil. Under the facility, revolving loans and letters of credit were provided subject to availability requirements which were determined pursuant to a borrowing base calculation as defined in the credit agreement. The borrowing base, as calculated, was primarily supported by cash, certain accounts receivable and certain inventory. Borrowings under the Wells Revolving Loan and Wells Term Loan bore interest based on separate predetermined pricing grids that allowed us to choose between base rate loans or LIBOR rate loans. Additionally, the Wells ABL required us to pay a quarterly unused credit commitment fee.

Lion Term Loan

Our subsidiary, Lion Oil, had a term loan credit facility with Fifth Third, as administrative agent, and a syndicate of lenders, which, as amended and restated, had a total loan size of $275.0 million (the "Lion Term Loan"). This facility was extinguished in connection with the Refinancing on March 30, 2018. The Lion Term Loan required Lion Oil to make quarterly principal amortization payments of approximately $6.9 million each, commencing on September 30, 2015, with a final balloon payment due at maturity on May 14, 2020. The Lion Term Loan was secured by, among other things, (i) certain assets of Lion Oil and its subsidiaries, (ii) all shares in Lion Oil, (iii) any subordinated and common units of Delek Logistics held by Lion Oil, and (iv) the ALJ Shares. Additionally, the Lion Term Loan was guaranteed by Old and New Delek and the subsidiaries of Lion Oil. Interest on the unpaid balance of the Lion Term Loan was computed at a rate per annum equal to LIBOR or a base rate, at our election, plus the applicable margins, subject in each case to an all-in interest rate floor of 5.50% per annum.

Alon Partnership

Revolving Credit Facility

Alon USA, LP, a wholly-owned subsidiary of the Alon Partnership had a $240.0 million asset-based revolving credit facility with Israel Discount Bank of New York, as administrative agent (the “Alon Partnership Credit Facility”) that was to mature on May 26, 2018. This facility was extinguished in connection with the Refinancing on March 30, 2018. The Alon Partnership Credit Facility could be used both for borrowings and the issuance of letters of credit subject to a limit of the lesser of the facility amount or the borrowing base amount under the facility. Borrowings under the Alon Partnership Credit Facility bore interest at LIBOR or base rate, at our election, plus the applicable margins. The Alon Partnership Credit Facility was secured by a first priority lien on the Alon Partnership’s cash, accounts receivables, inventories and related assets and a second priority lien on the Alon Partnership’s fixed assets and other specified property. Additionally, the Alon Partnership Credit Facility required the payment of a quarterly fee on the average unused revolving commitment.

Partnership Term Loan Credit Facility

The Alon Partnership had a $250.0 million term loan with Credit Suisse AG, as administrative agent (the “Alon Partnership Term Loan”). This term loan was extinguished in connection with the Refinancing on March 30, 2018. The Alon Partnership Term Loan required principal payments of $2.5 million per annum paid in equal quarterly installments until maturity in November 2018, at which time a balloon payment was to be due for any remaining principal outstanding. The Alon Partnership Term Loan bore interest at a rate per annum equal to LIBOR (subject to a floor of 1.25%) or a base rate plus the applicable margins. The Alon Partnership Term Loan was guaranteed by Alon USA Partners GP, LLC, Alon Assets, Inc. and certain subsidiaries of the Alon Partnership, and was secured by a first priority lien on all of the Alon Partnership’s fixed assets and other specified property, as well as on the general partner interest in the Alon Partnership held by the Alon General Partner, and a second priority lien on the Alon Partnership’s cash, accounts receivables, inventories and related assets.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Alon Term Loan Credit Facilities

Alon Energy Term Loan

On March 27, 2014, Alon issued a promissory note to Bank Hapoalim B.M. in an original principal amount of $25.0 million (“Alon Energy Term Loan”), that was to mature in March 2019, but was refinanced on December 29, 2017 with the proceeds of a new promissory note to Bank Hapoalim in an original principal amount of $38.0 million ("New Alon Energy Term Loan"), maturing on December 29, 2022. The New Alon Energy Term Loan was extinguished in connection with the Refinancing on March 30, 2018. The New Alon Energy Term Loan required quarterly principal amortization payments of approximately $1.4 million each, commencing on March 30, 2018, and incurred interest at an annual rate equal to LIBOR plus an applicable margin. Additionally, Delek guaranteed all obligations under the New Alon Energy Term Loan.

Alon Asphalt Term Loan

Alon had a term loan owed to Export Development Canada secured by liens on certain of our asphalt terminals (“Alon Asphalt Term Loan”) in an original principal amount of $35.0 million. This loan was prepaid on March 29, 2018 in connection with the Refinancing on March 30, 2018. The Alon Asphalt Term Loan was guaranteed by Delek and certain subsidiaries of Alon and was also secured by pledges of equity of certain subsidiaries of Alon. The Alon Asphalt Term Loan required quarterly principal amortization payments of $3.9 million, commencing December 2018 until maturity in December 2020. The Alon Asphalt Term Loan bore interest at a rate equal to LIBOR plus an applicable margin.

Alon Energy Letter of Credit Facility

Alon had a Letter of Credit Facility with Israel Discount Bank of New York (the “Alon Energy Letter of Credit Facility”) that was used for the issuance of standby letters of credit. The facility was amended on November 30, 2017, to, among other things, extend the maturity date of the facility to February 28, 2018 and to reduce the maximum commitment under the facility from $60.0 million to $45.0 million effective December 31, 2017, and was again amended on February 27, 2018 to extend the maturity date to March 29, 2018 when it expired. As collateral for the Alon Energy Letter of Credit Facility, we were required to pledge sufficient Alon Partnership common units with an initial collateral value of at least $100.0 million. Alon Assets, Inc. (“Alon Assets”) was a guarantor under the Alon Energy Letter of Credit Facility. Additionally, the Alon Energy Letter of Credit Facility required the payment of a quarterly fee on the average unused commitment.

Alon Retail Credit Agreement

Alon wholly-owned subsidiaries Southwest Convenience Stores, LLC and Skinny’s LLC, (collectively, “Alon Retail”), had a credit agreement (“Alon Retail Credit Agreement”), that was to mature in March 2019, with Wells Fargo Bank, National Association, as administrative agent. This credit agreement was extinguished in connection with the Refinancing on March 30, 2018. The Alon Retail Credit Agreement included a term loan in an original principal amount of $110.0 million and a $10.0 million revolving credit facility. The Alon Retail Credit Agreement also included an accordion feature that provided for incremental term loans up to $30.0 million. In August 2015, Alon borrowed $11.0 million using the accordion feature and amended the Alon Retail Credit Agreement to restore the undrawn amount of the accordion feature back to $30.0 million. Borrowings under the Alon Retail Credit Agreement bore interest at LIBOR or base rate, at our election, plus an applicable margin, determined quarterly based upon Alon Retail’s leverage ratio. Principal payments on the term loan borrowings were made in quarterly installments based on a 15-year amortization schedule. Obligations under the Alon Retail Credit Agreement were secured by a first priority lien on substantially all of the assets of Alon Retail and its subsidiaries. The Alon Retail Credit Agreement required us to pay a leverage ratio dependent quarterly fee on the average unused revolving commitment.

Future Principal Maturities

Principal maturities of Delek's existing third-party debt instruments for the next five years (inclusive of the remainder of 2018) and thereafter are as follows as of September 30, 2018 (in millions):



	October 1 to December 31, 2018		2019		2020		2021		2022		Thereafter		Total
Revolving Credit Facility	$	—	$	—	$	—	$	—	$	—	$	300.0	$	300.0
Term Loan Credit Facility	1.8		7.0		7.0		7.0		7.0		666.7		696.5
DKL Credit Facility	—		—		—		—		—		533.2		533.2
DKL Notes	—		—		—		—		—		250.0		250.0
Reliant Bank Revolver	—		—		30.0		—		—		—		30.0
Promissory Notes	—		25.0		25.0		20.0		—		—		70.0
Convertible Notes	—		—		—		—		—		—		—
Total	$	1.8	$	32.0	$	62.0	$	27.0	$	7.0	$	1,749.9	$	1,879.7

Notes to Condensed Consolidated Financial Statements (Unaudited)

Interest-Rate Derivative Instruments

Effective with the Delek/Alon Merger, we assumed Alon's interest rate swap agreements that were to mature in March 2019, which effectively fixed the variable LIBOR interest component of the term loans within the Alon Retail Credit Agreement. These interest rate swap agreements were terminated in connection with the Refinancing on March 30, 2018. These interest rate swaps were accounted for as cash flow hedges. See Note 16 for further information regarding the interest rate swap agreements.

Note 9 - Other Assets and Liabilities

The detail of other current assets is as follows (in millions):



Other Current Assets	September 30, 2018		December 31, 2017
Prepaid expenses	$	15.0	$	17.6
Short-term derivative assets (see Note 16)	30.2		15.9
Income and other tax receivables	15.1		74.9
RINs Obligation surplus (see Note 15)	—		1.1
Commodity investments	6.9		—
Other	21.2		20.4
Total	$	88.4	$	129.9

The detail of other non-current assets is as follows (in millions):



Other Non-Current Assets	September 30, 2018		December 31, 2017
Prepaid tax asset	$	—	$	56.2
Deferred financing costs	11.7		5.9
Long-term income tax receivables	2.1		2.1
Supply and Offtake receivable	32.7		46.3
Long-term derivative assets (see Note 16)	3.6		—
Other	9.9		16.3
Total	$	60.0	$	126.8

The detail of accrued expenses and other current liabilities is as follows (in millions):



Accrued Expenses and Other Current Liabilities	September 30, 2018		December 31, 2017
Income and other taxes payable	$	128.1	$	154.1
Short-term derivative liabilities (see Note 16)	19.8		54.4
Interest payable	13.2		13.0
Employee costs	41.4		46.6
Environmental liabilities (see Note 17)	7.3		7.2
Product financing agreements	—		72.3
RINs Obligation deficit (see Note 15)	8.0		130.8
Accrued utilities	7.5		9.4
Tank inspection liabilities	7.7		10.7
Crude liabilities	127.1		34.5
Other	24.5		31.9
Total	$	384.6	$	564.9

Notes to Condensed Consolidated Financial Statements (Unaudited)

The detail of other non-current liabilities is as follows (in millions):



Other Non-Current Liabilities	September 30, 2018		December 31, 2017
Pension and other postemployment benefit liabilities, net (see Note 18)	$	4.5	$	37.0
Long-term derivative liabilities (see Note 16)	0.4		0.9
Liability for unrecognized tax benefits	7.5		6.1
Above-market leases	9.8		11.2
Tank inspection liabilities	9.9		11.7
Other	5.7		16.1
Total	$	37.8	$	83.0

Note 10 - Stockholders' Equity

Changes to equity during the nine months ended September 30, 2018 are presented below (in millions, except per share amounts):



	Delek Stockholders' Equity			Non-Controlling Interest in Subsidiaries			Total Stockholders' Equity
Balance at December 31, 2017	$	1,650.6		$	313.6		$	1,964.2
Net income	224.0			29.0			253.0
Net unrealized loss on cash flow hedges, net of income tax benefit of $2.3 million and ineffectiveness gain of $0.7 million	(8.2		)	—			(8.2		)
Foreign currency translation loss	(0.4		)	—			(0.4		)
Other comprehensive income related to postretirement benefit plans	7.0			—			7.0
Other comprehensive income related to interest rate contracts	(0.5		)	—			(0.5		)
Common stock dividends ($0.70 per share)	(58.8		)	—			(58.8		)
Distributions to non-controlling interests	—			(21.5		)	(21.5		)
Equity-based compensation expense	15.3			0.3			15.6
Issuance of stock for non-controlling interest repurchase, net of tax	140.5			(127.0		)	13.5
De-recognition of non-controlling interest	—			(18.7		)	(18.7		)
Cumulative effect of adopting accounting principle regarding income tax effect of intra-equity transfers (see Note 1)	(29.9		)	—			(29.9		)
Shares issued in connection with settlement of Convertible Notes (see Note 8)	(0.3		)	—			(0.3		)
Shares received in connection with exercise of Call Options (see Note 8)	0.3			—			0.3
Repurchase of common stock	(207.4		)	—			(207.4		)
Taxes due to the net settlement of equity-based compensation	(10.8		)	—			(10.8		)
Balance at September 30, 2018	$	1,721.3		$	175.8		$	1,897.1

Dividends

During the nine months ended September 30, 2018, our Board of Directors declared the following dividends:



Date Declared	Dividend Amount Per Share	Record Date	Payment Date
February 26, 2018	$0.20	March 12, 2018	March 26, 2018
May 7, 2018	$0.25	May 21, 2018	June 4, 2018
August 7, 2018	$0.25	August 21, 2018	September 4, 2018

Notes to Condensed Consolidated Financial Statements (Unaudited)

Stock Repurchase Program

In December 2016, our Board of Directors authorized a share repurchase program for up to $150.0 million of Delek common stock. Any share repurchases under the repurchase program may be implemented through open market transactions or in privately negotiated transactions, in accordance with applicable securities laws. The timing, price and size of repurchases will be made at the discretion of management and will depend on prevailing market prices, general economic and market conditions and other considerations. The repurchase program does not obligate us to acquire any particular amount of stock and does not expire. We repurchased 762,623 shares, for a total of $25.0 million, pursuant to this repurchase program in December 2017.

During the three and nine months ended September 30, 2018, 1,906,308 and 4,847,511 shares of our common stock were repurchased, for a total of $92.1 million and $207.4 million, respectively. The purchases during the nine months ended September 30, 2018 include the 2.0 million shares of our common stock purchased from Alon Israel in connection with Delek’s rights pursuant to a Stock Purchase Agreement dated April 14, 2015, by and between Delek and Alon Israel. Alon Israel delivered a right of first offer notice to Delek on January 16, 2018, informing Delek of Alon Israel’s intention to sell the 2.0 million shares, and Delek accepted such offer on January 17, 2018. The total purchase price for the 2.0 million shares was approximately $75.3 million, or $37.64 per share.

On February 26, 2018, the Board of Directors approved a new $150.0 million authorization to repurchase Delek common stock. This amount has no expiration date and is in addition to any remaining amounts previously authorized. As of September 30, 2018, there was approximately $67.6 million of authorization remaining under Delek's aggregate stock repurchase program (based on repurchases that had settled as of September 30, 2018). On November 6, 2018, the Board of Directors authorized the repurchase of an additional $500.0 million of Delek common stock. This new authorization has no expiration and is in addition to any remaining amounts previously authorized.

Note 11 - Income Taxes

Under ASC 740, Income Taxes (“ASC 740”), companies are required to apply an estimated annual tax rate to interim period results on a year-to-date basis; however, the estimated annual tax rate should not be applied to interim financial results if a reliable estimate cannot be made. In this situation, the interim tax rate should be based on actual year-to-date results. We used an estimated annual tax rate to record income taxes for the three and nine months ended September 30, 2018, and an actual year-to-date effective tax rate to record income taxes for the three and nine months ended September 30, 2017.

On December 22, 2017, the U.S. government enacted the Tax Reform Act, which makes broad and complex changes to the U.S. tax code, including a permanent reduction in the U.S. federal corporate tax rate from 35% to 21% (“Rate Reduction”). The Tax Reform Act also puts into place new tax laws that will apply prospectively, which include, but are not limited to, modifying the rules governing the deductibility of certain executive compensation; extending and modifying the additional first-year depreciation deduction to accelerate expensing of certain qualified property; creating a limitation on deductible interest expense; and, changing rules related to uses and limitations of net operating loss carryforwards.

We are applying the guidance in Staff Accounting Bulletin 118 (“SAB 118”), when accounting for the effects of the Tax Reform Act. SAB 118 provides a measurement period that should not extend beyond one year from the Tax Reform Act enactment date for companies to complete the accounting under ASC 740. In accordance with SAB 118, a company must reflect the income tax effects of those aspects of the Tax Reform Act for which the accounting under ASC 740 is complete. To the extent that a company’s accounting for certain income tax effects of the Tax Reform Act is incomplete but it is able to determine a reasonable estimate, it must record a provisional estimate to be included in the financial statements. If a company cannot determine a provisional estimate to be included in the financial statements, it should continue to apply ASC 740 on the basis of the provision of the tax laws that were in effect immediately before the enactment of the Tax Reform Act.

The Company has not completed the accounting for the income tax effects of the Tax Reform Act. At December 31, 2017, the Company recorded a discrete net tax benefit of $166.9 million primarily related to provisional amounts under SAB 118 for the remeasurement of U.S. deferred tax assets and liabilities due to the Rate Reduction. Upon further analyses of certain aspects of the Act and refinement of our calculations during the three and nine months ended September 30, 2018, we adjusted our provisional amounts by an additional benefit (expense) of $0.5 million and $(2.1) million, respectively, which is included as a component of income tax expense from continuing operations. We also had a reclassification of $1.6 million from accumulated other comprehensive income to retained earnings for stranded tax effects as of September 30, 2018 resulting from the Tax Reform Act. See Note 1 for further information. We will continue to analyze and refine our calculations related to the measurement of these balances as supplemental legislation, regulatory guidance or evolving technical interpretations become available.

On January 1, 2018, we decreased prepaid income taxes by $59.4 million, increased income taxes payable by $3.0 million, decreased deferred tax liabilities by $32.5 million and decreased retained earnings by $29.9 million for the cumulative effect related to new guidance that requires recognizing the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs - see Note 1 for further information.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Our effective tax rate was 21.5% and 20.3% for the three and nine months ended September 30, 2018, respectively, compared to 53.0% and 52.3% for the three and nine months ended September 30, 2017, respectively. The change in our effective tax rate was primarily due to the following: reduction to Federal tax rate attributable to continued adjustments to properly consider the impact of the Tax Reform Act (which reduced the U.S. federal corporate tax rate from 35% to 21%, as discussed above), combined with income tax benefit for federal tax credits attributable to the Company’s biodiesel blending operations for 2017 and the reversal of the deferred tax asset related to the previously held equity method investment in Alon in the third quarter of 2017, partially offset by tax expense associated with the impairment of assets held for sale during the first quarter of 2017.

Note 12 - Equity-Based Compensation

Delek US Holdings, Inc. 2006 and 2016 and Alon USA Energy, Inc. 2005 Long-Term Incentive Plans (the "Incentive Plans")

On May 8, 2018, the Company’s stockholders approved an amendment to the Delek US Holdings, Inc. 2016 Long-Term Incentive Plan that increased the number of shares of Common Stock available for issuance under this plan by 4,500,000 shares to 8,900,000 shares.

Compensation expense related to equity-based awards granted under the Incentive Plans amounted to $5.4 million ($4.3 million, net of taxes) and $15.6 million ($12.3 million, net of taxes) for the three and nine months ended September 30, 2018, respectively, and $4.1 million ($2.7 million, net of taxes) and $11.1 million ($7.2 million, net of taxes) for the three and nine months ended September 30, 2017, respectively. These amounts are included in general and administrative expenses in the accompanying condensed consolidated statements of income.

As of September 30, 2018, there was $50.3 million of total unrecognized compensation cost related to non-vested share-based compensation arrangements, which is expected to be recognized over a weighted-average period of 3.1 years.

We issued 90,552 and 535,613 shares of common stock as a result of exercised or vested equity-based awards during the three and nine months ended September 30, 2018, respectively, and 57,149 and 257,602 during the three and nine months ended September 30, 2017, respectively. These amounts are net of 146,193 and 980,954 shares withheld to satisfy employee tax obligations related to the exercises and vestings during the three and nine months ended September 30, 2018, respectively, and 48,286 and 200,026 shares during the three and nine months ended September 30, 2017, respectively.

Delek Logistics GP, LLC 2012 Long-Term Incentive Plan

Compensation expense for Delek Logistics GP equity-based awards was $0.2 million ($0.2 million, net of taxes) and $0.5 million ($0.4 million, net of taxes) for the three and nine months ended September 30, 2018, respectively, and $0.4 million ($0.3 million, net of taxes) and $1.3 million ($0.8 million, net of taxes) for the three and nine months ended September 30, 2017, respectively. These amounts are included in general and administrative expenses in the accompanying condensed consolidated statements of income.

As of September 30, 2018, there was $0.4 million of total unrecognized compensation cost related to non-vested share-based compensation arrangements, which is expected to be recognized over a weighted-average period of 0.6 years.

Note 13 - Earnings (Loss) Per Share

Basic earnings per share (or "EPS") is computed by dividing net income (loss) by the weighted average common shares outstanding. Diluted earnings per share is computed by dividing net income (loss), as adjusted for changes to income that would result from the assumed settlement of the dilutive equity instruments included in diluted weighted average common shares outstanding, by the diluted weighted average common shares outstanding. For all periods presented, we have outstanding various equity-based compensation awards that are considered in our diluted EPS calculation when to do so would not be anti-dilutive, and is inclusive of awards disclosed in Note 12 to these condensed consolidated financial statements. For those instruments that are indexed to our common stock, they are generally dilutive when the market price of the underlying indexed share of common stock is in excess of the exercise price. Additionally, in connection with the Delek/Alon Merger (disclosed in Note 2), we assumed certain equity instruments, including conversion options (associated with Convertible Debt) and Warrants, that may be dilutive (see discussion of these instruments in Note 8). The Convertible Debt conversion options were dilutive during the period they were outstanding when the incremental EPS calculated by dividing the increase in income associated with the elimination of interest expense on the convertible debt, net of tax, by the number of shares that would be issued upon conversion using the treasury stock method (which is applicable because of the cash settlement feature associated with the underlying principal) is dilutive to the overall diluted EPS calculation. The Warrants are generally dilutive during the period they are outstanding when the market price of the underlying indexed share of common stock is in excess of the exercise price. All such instruments that may otherwise be dilutive may not be dilutive when there is net loss for the period. We also assumed Call Options in connection with the Delek/Alon Merger which were not reflected in the diluted weighted average common shares outstanding because to do so would have been antidilutive.

Notes to Condensed Consolidated Financial Statements (Unaudited)

The following table sets forth the computation of basic and diluted earnings per share.



	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2018		2017			2018			2017
Numerator:
Numerator for EPS - continuing operations
Income from continuing operations	$	185.8	$	118.5		$	261.5		$	101.6
Less: Income from continuing operations attributed to non-controlling interest	6.5		10.0			20.9			19.8
Income from continuing operations attributable to Delek (numerator for basic EPS - continuing operations attributable to Delek)	179.3		108.5			240.6			81.8
Interest on convertible debt, net of tax	0.7		—			2.5			—
Numerator for diluted EPS - continuing operations attributable to Delek	$	180.0	$	108.5		$	243.1		$	81.8

Numerator for EPS - discontinued operations
Income (loss) from discontinued operations	$	0.5	$	(4.1	)	$	(8.5	)	$	(4.1	)
Less: Income from discontinued operations attributed to non-controlling interest	—		—			8.1			—
Income (loss) from discontinued operations attributable to Delek	$	0.5	$	(4.1	)	$	(16.6	)	$	(4.1	)

Weighted average common shares outstanding (denominator for basic EPS)	83,575,122		80,581,762			83,294,473			68,272,918
Dilutive effect of convertible debt	2,176,140		—			2,183,186			—
Dilutive effect of warrants	1,683,722		—			1,291,156			—
Dilutive effect of stock-based awards	1,586,276		663,643			1,600,298			703,056
Weighted average common shares outstanding, assuming dilution	89,021,260		81,245,405			88,369,113			68,975,974

EPS:
Basic income (loss) per share:
Income from continuing operations	$	2.15	$	1.35		$	2.89		$	1.20
Income (loss) from discontinued operations	$	0.01	(0.05		)	$	(0.20	)	(0.06		)
Total basic income per share	$	2.16	$	1.30		$	2.69		$	1.14
Diluted income (loss) per share:
Income from continuing operations	$	2.02	$	1.34		$	2.75		$	1.19
Income (loss) from discontinued operations	$	0.01	(0.05		)	$	(0.19	)	(0.06		)
Total diluted income per share	$	2.03	$	1.29		$	2.56		$	1.13

The following equity instruments were excluded from the diluted weighted average common shares outstanding because their effect would be antidilutive:

Antidilutive stock-based compensation (because average share price is less than exercise price)	1,014,057		3,996,185			1,208,648			4,006,310

Antidilutive convertible debt instruments (because average share price is less than exercise price)	—		5,623,304			—			3,748,869

Antidilutive warrants (because average share price is less than exercise price)	—		5,612,581			—			3,741,721

Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 14 - Segment Data

We aggregate our operating units into three reportable segments: refining, logistics and retail.

Our corporate activities, results of certain immaterial operating segments, including our Canadian crude trading operations, Alon's asphalt terminal operations effective with the Delek/Alon Merger, our equity method investment in Alon prior to the Delek/Alon Merger, as well as our discontinued Paramount and Long Beach, California refinery and California renewable fuels facility operations (acquired as part of the Delek/Alon Merger - see Note 5 for further discussion), and intercompany eliminations are reported in the corporate, other and eliminations segment. On March 16, 2018, Delek sold to World Energy, LLC (i) all of Delek’s membership interests in the California renewable fuels facility, (ii) certain refining assets and other related assets located in Paramount, California and (iii) certain associated tank farm and pipeline assets and other related assets located in California, as further discussed in Note 5. On May 21, 2018, Delek sold certain assets and operations of four asphalt terminals (included in Delek's corporate/other segment), as well as an equity method investment in an additional asphalt terminal, to an affiliate of Andeavor, as further discussed in Note 5. The transaction to dispose of certain assets and liabilities associated with our Long Beach, California refinery, to Bridge Point Long Beach, LLC, closed July 17, 2018, as further discussed in Note 5.

Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each of the reportable segments based on the segment contribution margin. Segment contribution margin is defined as net revenues less cost of materials and other and operating expenses, excluding depreciation and amortization. Operations which are not specifically included in the reportable segments are included in the corporate and other category, which primarily consists of net revenues, operating costs and expenses, depreciation and amortization expense and interest income and expense associated with our discontinued operations (see Note 5 for further discussion) and with our corporate headquarters.

The refining segment processes crude oil and other purchased feedstocks for the manufacture of transportation motor fuels, including various grades of gasoline, diesel fuel, aviation fuel, asphalt and other petroleum-based products that are distributed through owned and third-party product terminals. Prior to the Delek/Alon Merger, the refining segment had a combined nameplate capacity of 155,000 bpd, including the 75,000 bpd Tyler refinery and the 80,000 bpd El Dorado, Arkansas refinery (the "El Dorado refinery"). The refining segment also owns and operates two biodiesel facilities involved in the production of biodiesel fuels and related activities, located in Crossett, Arkansas and Cleburn, Texas. Effective with the Delek/Alon Merger, our refining segment now also includes the operations of a refinery located in Big Spring, Texas with a nameplate capacity of 73,000 bpd (the "Big Spring refinery"), a refinery located in Krotz Springs, Louisiana with a nameplate capacity of 74,000 bpd (the "Krotz Springs refinery) and a refinery located in Bakersfield, California. The Bakersfield, California refinery has not processed crude oil since 2012 due to the high cost of crude oil relative to product yield and low asphalt demand. Alon's petroleum-based products are marketed primarily in the south central, southwestern and western regions of the United States and also ships and sells gasoline into wholesale markets in the Southern and Eastern United States. Motor fuels are sold under the Alon brand through various terminals to supply Alon branded retail sites, including our retail segment convenience stores. In addition, Alon sells motor fuels through its wholesale distribution network on an unbranded basis.

Our refining segment has service agreements with our logistics segment, which, among other things, requires the refining segment to pay service fees based on the number of gallons sold and a sharing of a portion of the margin achieved in return for providing marketing, sales and customer services at the Tyler refinery, and effective March 1, 2018, at the Big Spring refinery (see Note 3 for further discussion regarding the new marketing agreement). These intercompany transaction fees in regards to the Tyler refinery were $5.7 million and $16.2 million during the three and nine months ended September 30, 2018, respectively, and $5.2 million and $14.8 million during the three and nine months ended September 30, 2017, respectively. The intercompany transaction fees in regards to the Big Spring refinery for the three and nine months ended September 30, 2018 were $3.3 million and $7.6 million, respectively. Additionally, the refining segment pays crude transportation, terminalling and storage fees to the logistics segment for the utilization of pipeline, terminal and storage assets, including effective March 1, 2018, those related to the Big Spring Logistic Assets Acquisition discussed further in Note 3. These fees were $54.1 million and $152.0 million during the three and nine months ended September 30, 2018, respectively, and $33.5 million and $97.7 million during the three and nine months ended September 30, 2017, respectively. The logistics segment also sold $0.3 million and $2.3 million of RINs to the refining segment during the three and nine months ended September 30, 2018, respectively, and $1.4 million and $3.9 million during the three and nine months ended September 30, 2017, respectively. The refining segment recorded sales revenues from the retail segment of $122.4 million and $340.9 million and from sales of asphalt to our other segment of $22.5 million and $33.6 million during the three and nine months ended September 30, 2018, respectively, and sales revenues from the logistics segment of $83.9 million and $265.7 million during the three and nine months ended September 30, 2018, respectively. The refining segment recorded revenues from sales to the retail segment of $90.6 million and sales of asphalt to our other segment of $7.7 million during the three and nine months ended September 30, 2017. Refining sales revenues from the logistics segment were $10.0 million and $27.1 million during the three and nine months ended September 30, 2017, respectively. All inter-segment transactions have been eliminated in consolidation.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Our logistics segment owns and operates crude oil and refined products logistics and marketing assets. The logistics segment generates revenue by charging fees for gathering, transporting and storing crude oil and for marketing, distributing, transporting and storing intermediate and refined products in select regions of the southeastern United States and west Texas for our refining segment and third parties, and sales of wholesale products in the west Texas market. The logistics segment is currently managing a long-term capital project on behalf of the Company for the construction of a gathering system in the Permian Basin and a long-haul crude oil pipeline that will originate in Midland, Texas and terminate in Houston, Texas. The logistics segment incurs the costs in connection with the construction of the assets and is subsequently reimbursed by the refining segment. These transactions are eliminated in consolidation.

Effective with the Delek/Alon Merger on July 1, 2017 (see Note 2), Delek's retail segment includes the operations of Alon's approximately 300 owned and leased convenience store sites located primarily in central and west Texas and New Mexico. These convenience stores typically offer various grades of gasoline and diesel under the Alon brand name and food products, food service, tobacco products, non-alcoholic and alcoholic beverages, general merchandise as well as money orders to the public, primarily under the 7-Eleven and Alon brand names. Substantially all of the motor fuel sold through our retail segment is supplied by our Big Spring refinery, which is transferred to the retail segment at prices substantially determined by reference to published commodity pricing information.

The following is a summary of business segment operating performance as measured by contribution margin for the period indicated (in millions):



	Three Months Ended September 30, 2018
(In millions)	Refining		Logistics		Retail		Corporate, Other and Eliminations			Consolidated
Net revenues (excluding intercompany fees and sales)	$	2,146.8	$	100.3	$	246.4	$	1.7		$	2,495.2
Intercompany fees and sales	228.8		63.8		—		(292.6		)	—
Operating costs and expenses:
Cost of materials and other	1,937.3		105.6		204.4		(276.8		)	1,970.5
Operating expenses (excluding depreciation and amortization presented below)	118.8		15.4		26.7		3.1			164.0
Segment contribution margin	$	319.5	$	43.1	$	15.3	$	(17.2	)	360.7
Depreciation and amortization	33.8		6.7		5.3		3.4			49.2
General and administrative expenses										58.0
Other operating income, net										(1.7		)
Operating income										$	255.2
Total assets	$	5,378.3	$	693.6	$	339.3	$	(252.5	)	$	6,158.7
Capital spending (excluding business combinations) ⁽¹⁾	$	51.1	$	2.9	$	1.9	$	30.2		$	86.1



	Nine Months Ended September 30, 2018
(In millions)	Refining ⁽²⁾		Logistics		Retail		Corporate, Other and Eliminations ⁽²⁾			Consolidated
Net revenues (excluding intercompany fees and sales)	$	6,331.1	$	319.8	$	700.8	$	60.2		$	7,411.9
Intercompany fees and sales	640.2		178.5		—		(818.7		)	—
Operating costs and expenses:
Cost of materials and other	5,994.8		330.6		578.5		(713.8		)	6,190.1
Operating expenses (excluding depreciation and amortization presented below)	346.7		42.9		76.5		13.5			479.6
Segment contribution margin	$	629.8	$	124.8	$	45.8	$	(58.2	)	742.2
Depreciation and amortization	99.1		19.7		16.8		10.8			146.4
General and administrative expenses										176.1
Other operating income, net										(9.4		)
Operating income										$	429.1
Capital spending (excluding business combinations) ⁽¹⁾	$	136.3	$	7.4	$	6.0	$	61.2		$	210.9

Notes to Condensed Consolidated Financial Statements (Unaudited)



	Three Months Ended September 30, 2017
	Refining		Logistics		Retail		Corporate, Other and Eliminations			Consolidated
Net revenues (excluding intercompany fees and sales)	$	2,005.5	$	90.6	$	213.9	$	60.6		$	2,370.6
Intercompany fees and sales	108.3		40.1		—		(148.4		)	—
Operating costs and expenses:
Cost of materials and other	1,823.2		89.1		174.6		(69.7		)	2,017.2
Operating expenses (excluding depreciation and amortization presented below)	110.5		10.7		25.8		6.2			153.2
Segment contribution margin	$	180.1	$	30.9	$	13.5	$	(24.3	)	200.2
Depreciation and amortization	33.2		5.5		3.7		4.5			46.9
General and administrative expenses										68.0
Other operating expense, net										0.7
Operating loss										$	84.6
Total assets ⁽³⁾	$	4,269.0	$	422.9	$	371.8	$	505.4		$	5,569.1
Capital spending (excluding business combinations)⁽⁴⁾	$	47.6	$	3.8	$	10.6	$	6.5		$	68.5



	Nine Months Ended September 30, 2017
	Refining		Logistics		Retail		Corporate, Other and Eliminations			Consolidated
Net revenues (excluding intercompany fees and sales)	$	4,240.9	$	270.5	$	213.9	$	58.1		$	4,783.4
Intercompany fees and sales	125.4		116.4		—		(241.8		)	—
Operating costs and expenses:
Cost of materials and other	3,888.5		266.7		174.6		(119.1		)	4,210.7
Operating expenses (excluding depreciation and amortization presented below)	212.9		31.0		25.8		6.8			276.5
Segment contribution margin	$	264.9	$	89.2	$	13.5	$	(71.4	)	296.2
Depreciation and amortization	76.9		16.4		3.7		8.4			105.4
General and administrative expenses										122.0
Other operating expense, net										1.0
Operating loss										$	67.8
Capital spending (excluding business combinations)⁽⁴⁾	$	69.6	$	8.7	$	10.6	$	9.8		$	98.7


⁽¹⁾	Capital spending excludes transaction costs capitalized in the amount of $0.4 million during the nine months ended September 30, 2018, that relate to the Big Spring Logistic Assets Acquisition.


⁽²⁾	The corporate, other and eliminations segment results of operations for the nine months ended September 30, 2018, includes Canada trading activity which was previously included and reported in the refining segment for the three months ended March 31, 2018.


⁽³⁾	Assets held for sale of $167.2 million are included in the corporate, other and eliminations segment as of September 30, 2017.


⁽⁴⁾	Capital spending excludes capital spending associated with the California Discontinued Entities of $0.4 million and the asset acquisition of pipeline assets totaling $12.1 million for the three and nine months ended September 30, 2017.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Property, plant and equipment and accumulated depreciation as of September 30, 2018 and depreciation expense by reporting segment for the three and nine months ended September 30, 2018 are as follows (in millions):



	Refining			Logistics			Retail			Corporate, Other and Eliminations			Consolidated
Property, plant and equipment	$	2,163.2		$	448.7		$	144.7		$	140.6		$	2,897.2
Less: Accumulated depreciation	(552.1		)	(134.1		)	(21.8		)	(46.8		)	(754.8		)
Property, plant and equipment, net	$	1,611.1		$	314.6		$	122.9		$	93.8		$	2,142.4
Depreciation expense for the three months ended September 30, 2018	$	31.7		$	6.7		$	5.2		$	3.4		$	47.0
Depreciation expense for the nine months ended September 30, 2018	$	92.0		$	19.6		$	16.3		$	10.8		$	138.7

In accordance with ASC 360, Delek evaluates the realizability of property, plant and equipment as events occur that might indicate potential impairment. There were no indicators of impairment of our property, plant and equipment as of September 30, 2018.

Note 15 - Fair Value Measurements

The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of Delek’s assets and liabilities that fall under the scope of ASC 825, Financial Instruments ("ASC 825").

Delek applies the provisions of ASC 820, Fair Value Measurements ("ASC 820"), which defines fair value, establishes a framework for its measurement and expands disclosures about fair value measurements. ASC 820 applies to our commodity and interest rate derivatives that are measured at fair value on a recurring basis. The standard also requires that we assess the impact of nonperformance risk on our derivatives. Nonperformance risk is not considered material to our financial statements as of September 30, 2018.

ASC 820 requires disclosures that categorize assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting our assumptions about pricing by market participants.

Commodity swaps, exchange-traded futures, options, physical commodity forward purchase and sale contracts (that do qualify as normal purchases or normal sales), and interest rate swaps are generally valued using industry-standard models that consider various assumptions, including quoted forward prices, spot prices, interest rates, time value, volatility factors and contractual prices for the underlying instruments, as well as other relevant economic measures. The degree to which these inputs are observable in the forward markets determines the classification as Level 2 or 3. Our contracts are valued based on exchange pricing and/or price index developers such as Platts or Argus and are, therefore, classified as Level 2. Commodity investments are valued using published market prices of the commodity on the applicable exchange and are, therefore, classified as Level 1.

The U.S. Environmental Protection Agency ("EPA") requires certain refiners to blend biofuels into the fuel products they produce pursuant to the EPA’s Renewable Fuel Standard - 2. Alternatively, credits called RINs, which may be generated and/or purchased, can be used to satisfy this obligation instead of physically blending biofuels ("RINs Obligation"). Our RINs Obligation surplus or deficit is based on the amount of RINs we must purchase, net of amounts internally generated and purchased and the price of those RINs as of the balance sheet date. The RINs Obligation surplus or deficit is categorized as Level 2, and is measured at fair value based on quoted prices from an independent pricing service.

In both March 2018 and March 2017, the El Dorado refinery received approval from the EPA for a small refinery exemption from the requirements of the renewable fuel standard for the 2017 and 2016 calendar years, respectively, which resulted in a reduction of our RINs Obligation and related cost of materials and other of approximately $59.3 million and $47.5 million for the nine months ended September 30, 2018 and September 30, 2017, respectively. In March 2018, the Krotz Springs refinery received such approval as well, which resulted in a reduction of our RINs Obligation and related cost of materials and other of approximately $31.6 million for the nine months ended September 30, 2018.

Our RIN commitment contracts are future commitments to purchase or sell RINs at fixed prices and quantities, which are used to manage the costs associated with our RINs Obligation. These RIN commitment contracts are categorized as Level 2, and are measured at fair value based on quoted prices from an independent pricing service. Changes in the fair value of these future RIN commitment contracts are recorded in cost of materials and other on the condensed consolidated statements of income.

Notes to Condensed Consolidated Financial Statements (Unaudited)

We have elected to account for our J. Aron step-out liability at fair value in accordance with ASC 825, as it pertains to the fair value option. This standard permits the election to carry financial instruments and certain other items similar to financial instruments at fair value on the balance sheet, with all changes in fair value reported in earnings. Our J. Aron step-out liability is categorized as Level 2, and is measured at fair value using market prices for the consigned crude oil and refined products we are required to repurchase from J. Aron at the end of the term of the Supply and Offtake Agreement. The J. Aron step-out liability is presented in the Obligation under Supply and Offtake Agreement line item of our condensed consolidated balance sheets. Gains (losses) related to the change in fair value are recorded as a component of cost of materials and other in the condensed consolidated statements of income.

Commodity investments represent those commodities (generally crude oil) physically on hand as a result of trading activities with physical forward contracts. Such investment stores are maintained on a weighted average cost basis for determining realized gains and losses on physical sales under forward contracts, and ending balances are adjusted to fair value at each reporting date. The unrealized loss on the commodity investments for the three and nine months ended September 30, 2018 totaled $3.5 million and $3.3 million, respectively.

The fair value hierarchy for our financial assets and liabilities accounted for at fair value on a recurring basis at September 30, 2018 and December 31, 2017, was as follows (in millions):



	As of September 30, 2018
	Level 1		Level 2			Level 3		Total
Assets
Commodity derivatives	$	—	$	589.1		$	—	$	589.1
Commodity investments	6.9		—			—		6.9
RIN commitment contracts	—		2.3			—		2.3
Total assets	6.9		591.4			—		598.3
Liabilities
Commodity derivatives	—		(601.9		)	—		(601.9		)
RIN commitment contracts	—		(8.4		)	—		(8.4		)
RINs Obligation deficit	—		(8.0		)	—		(8.0		)
J. Aron step-out liability	—		(478.7		)	—		(478.7		)
Total liabilities	—		(1,097.0		)	—		(1,097.0		)
Net liabilities	$	6.9	$	(505.6	)	$	—	$	(498.7	)



	As of December 31, 2017
	Level 1		Level 2			Level 3		Total
Assets
Commodity derivatives	$	—	$	178.0		$	—	$	178.0
RIN commitment contracts	—		1.4			—		1.4
RINs Obligation surplus	—		1.1			—		1.1
Total assets	—		180.5			—		180.5
Liabilities
Interest rate derivatives	—		(0.9		)	—		(0.9		)
Commodity derivatives	—		(203.9		)	—		(203.9		)
RIN commitment contracts	—		(24.0		)	—		(24.0		)
RINs Obligation deficit	—		(130.8		)	—		(130.8		)
J. Aron step-out liability	—		(435.6		)	—		(435.6		)
Total liabilities	—		(795.2		)	—		(795.2		)
Net liabilities	$	—	$	(614.7	)	$	—	$	(614.7	)

Notes to Condensed Consolidated Financial Statements (Unaudited)

The derivative values above are based on analysis of each contract as the fundamental unit of account as required by ASC 820. In the table above, derivative assets and liabilities with the same counterparty are not netted where the legal right of offset exists. This differs from the presentation in the financial statements which reflects our policy, wherein we have elected to offset the fair value amounts recognized for multiple derivative instruments executed with the same counterparty and where the legal right of offset exists. As of September 30, 2018 and December 31, 2017, $32.5 million and $10.0 million, respectively, of cash collateral was held by counterparty brokerage firms and has been netted with the net derivative positions with each counterparty. See Note 16 for further information regarding derivative instruments.

Note 16 - Derivative Instruments

We use the majority of our derivatives to reduce normal operating and market risks with the primary objective of reducing the impact of market price volatility on our results of operations. As such, our use of derivative contracts is aimed at:


•	limiting the exposure to price fluctuations of commodity inventory above or below target levels at each of our segments;


•	managing our exposure to commodity price risk associated with the purchase or sale of crude oil, feedstocks and finished grade fuel products at each of our segments;


•	managing the cost of our RINs Obligation using future commitments to purchase or sell RINs at fixed prices and quantities; and


•	limiting the exposure to interest rate fluctuations on our floating rate borrowings.

We primarily utilize commodity swaps, futures, forward contracts and options contracts, generally with maturity dates of three years or less, and from time to time interest rate swap agreements to achieve these objectives. Futures contracts are standardized agreements, traded on a futures exchange, to buy or sell the commodity at a predetermined price at a specified future date. Options provide the right, but not the obligation to buy or sell the commodity at a specified price in the future. Commodity swap and futures contracts require cash settlement for the commodity based on the difference between a fixed or floating price and the market price on the settlement date, and options require payment of an upfront premium. Because these derivatives are entered into to achieve objectives specifically related to our inventory and production risks, such gains and losses (to the extent not designated as accounting hedges and recognized on an unrealized basis in other comprehensive income) are recognized in cost of materials and other.

Interest rate swap agreements economically hedge floating rate debt by exchanging interest rate cash flows, based on a notional amount from a floating rate to a fixed rate. Effective with the Delek/Alon Merger, we had four interest rate swap agreements (maturing March 2019) that effectively fixed the variable LIBOR interest component of the term loans within the Alon Retail Credit Agreement. The aggregate notional amount under these agreements were to cover approximately 77% of the outstanding principal of these term loans throughout the duration of the interest rate swaps. These interest rate swap agreements were terminated due to the extinguishment of the Alon Retail Credit Agreement in connection with the Refinancing on March 30, 2018, resulting in a reclassification of unrealized loss of $0.6 million from accumulated other comprehensive income to interest expense on the condensed consolidated income statement during the nine months ended September 30, 2018 - see Note 8 for further information.

Forward contracts are agreements to buy or sell a commodity at a predetermined price at a specified future date, and for our transactions, generally require physical delivery. Forward contracts where the underlying commodity will be used or sold in the normal course of business qualify as normal purchases and normal sales pursuant to ASC 815 Derivatives and Hedging ("ASC 815") and are not accounted for as derivative instruments. Rather, such forward contracts are accounted for under other applicable GAAP. Forward contracts entered into for trading purposes that do not meet the normal purchases, normal sales exception are accounted for as derivative instruments. As of and for the three and nine months ended September 30, 2018, all of our forward contracts that were accounted for as derivative instruments consisted of contracts related to our Canadian crude trading operations. Since Canadian crude trading activity is not related to managing supply or pricing risk of inventory that will be used in production, such unrealized and realized gains and losses are recognized in other operating income (expense), net rather than cost of materials and other on the accompanying condensed consolidated incomes statement. There were no forward contract transactions that were accounted for as derivatives during the three and nine months ended September 30, 2017, and there were no forward contract derivative assets or liabilities outstanding as of December 31, 2017.

Futures, swaps or other commodity related derivative instruments that are utilized to specifically hedge our Canadian forward contract or investment positions are recognized in other operating income (expense), net because that is where the related underlying transactions are reflected.

At this time, we do not believe there is any material credit risk with respect to the counterparties to any of our derivative contracts.

From time to time, we also enter into future commitments to purchase or sell RINs at fixed prices and quantities, which are used to manage the costs associated with our RINs Obligation. These future RIN commitment contracts meet the definition of derivative instruments under ASC 815, and are recorded at estimated fair value in accordance with the provisions of ASC 815. Changes in the fair value of these future RIN commitment contracts are recorded in cost of materials and other on the condensed consolidated statements of income.

Notes to Condensed Consolidated Financial Statements (Unaudited)

In accordance with ASC 815, certain of our commodity swap contracts and our interest rate agreements have been designated as cash flow hedges and the effective portion of the change in fair value between the execution date and the end of period (or early termination date in regards to the four Alon Retail interest rate swaps discussed above) has been recorded in other comprehensive income. The effective portion of the fair value of these contracts is recognized in income at the time the positions are closed and the hedged transactions are recognized in income. In regards to our interest rate swap agreements, the amount of losses in accumulated other comprehensive income were reclassified into earnings as a result of the discontinuance of cash flow hedges since the originally forecasted Alon Retail Credit Agreement interest payments will not occur by the end of the originally specified time period due to the Refinancing on March 30, 2018, as discussed above.

The following table presents the fair value of our derivative instruments as of September 30, 2018 and December 31, 2017. The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under our master netting arrangements, including cash collateral on deposit with our counterparties. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements. As a result, the asset and liability amounts below differ from the amounts presented in our condensed consolidated balance sheets. See Note 15 for further information regarding the fair value of derivative instruments (in millions):



		September 30, 2018					December 31, 2017
Derivative Type	Balance Sheet Location	Assets		Liabilities			Assets		Liabilities
Derivatives not designated as hedging instruments:
Commodity derivatives⁽¹⁾	Other current assets	$	376.6	$	(378.7	)	$	164.6	$	(162.0	)
Commodity derivatives⁽¹⁾	Other current liabilities	18.0		(28.4		)	13.4		(28.3		)
Commodity derivatives⁽¹⁾	Other long-term assets	45.3		(46.4		)	—		—
Commodity derivatives⁽¹⁾	Other long-term liabilities	0.7		(1.1		)	—		—
RIN commitment contracts⁽²⁾	Other current assets	2.3		—			1.4		—
RIN commitment contracts⁽²⁾	Other current liabilities	—		(8.4		)	—		(24.0		)

Derivatives designated as hedging instruments:
Commodity derivatives ⁽¹⁾	Other current assets	128.5		(131.8		)	—		—
Commodity derivatives⁽¹⁾	Other current liabilities	—		(0.2		)	—		(13.6		)
Commodity derivatives⁽¹⁾	Other long-term assets	20.0		(15.3		)	—		—
Interest rate derivatives	Other long term-liabilities	—		—			—		(0.9		)
Total gross fair value of derivatives		$	591.4	$	(610.3	)	$	179.4	$	(228.8	)
Less: Counterparty netting and cash collateral⁽³⁾		557.6		(590.1		)	163.5		(173.6		)
Total net fair value of derivatives		$	33.8	$	(20.2	)	$	15.9	$	(55.2	)


⁽¹⁾	As of September 30, 2018 and December 31, 2017, we had open derivative positions representing 152,355,222 and 35,978,000 barrels, respectively, of crude oil and refined petroleum products. Of these open positions, contracts representing 16,013,000 and 575,000 barrels were designated as cash flow hedging instruments as of September 30, 2018 and December 31, 2017, respectively.


⁽²⁾	As of September 30, 2018 and December 31, 2017, we had open RIN commitment contracts representing 58,955,000 and 163,361,320 RINs, respectively.


⁽³⁾	As of September 30, 2018 and December 31, 2017, $32.5 million and $10.0 million, respectively, of cash collateral held by counterparties has been netted with the derivatives with each counterparty.

Notes to Condensed Consolidated Financial Statements (Unaudited)

Total losses on our hedging derivatives and RIN commitment contracts recognized in the condensed consolidated statements of income are as follows (in millions):



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
Losses on commodity derivatives not designated as hedging instruments recognized in cost of materials and other ⁽¹⁾	$	(9.3	)	$	(15.5	)	$	(23.7	)	$	(5.6	)
Losses on commodity derivatives not designated as hedging instruments recognized in other operating income (expense), net ^{(1) (2)}	(0.6		)	—			(3.5		)	—
Realized (losses) gains reclassified out of OCI on commodity derivatives designated as cash flow hedging instruments	(9.6		)	1.0			(18.4		)	(38.5		)
Gains recognized on commodity derivatives due to cash flow hedging ineffectiveness	—			0.1			0.7			0.5
Total losses	$	(19.5	)	$	(14.4	)	$	(44.9	)	$	(43.6	)

⁽¹⁾

Losses on commodity derivatives that are economic hedges but not designated as hedging instruments include unrealized gains (losses) of $13.0 million and $2.8 million for the months ended September 30, 2018, respectively, and $(10.9) million and $(11.0) million for the months ended September 30, 2017, respectively. Of these amounts, approximately $5.9 million for the months ended September 30, 2018, and $(6.5) million for the months ended September 30, 2017, respectively, represent unrealized gains (losses) where the instrument has matured but where it has not cash settled as of period end. Derivative instruments that have matured but not cash settled at the balance sheet date continue to be reflected in derivative assets or liabilities on our balance sheet.


⁽²⁾	See separate table below for disclosures about "trading derivatives."

For cash flow hedges, no component of the derivative instruments’ gains or losses was excluded from the assessment of hedge effectiveness for the three and nine months ended September 30, 2018 or 2017. As of September 30, 2018 and December 31, 2017, gains of $1.1 million (related to Midland to Cushing crude price differentials at our refineries) and gains of $7.6 million (related to future purchases of crude oil), respectively, on cash flow hedges, net of tax, remained in accumulated other comprehensive income. Losses of $14.5 million, net of tax, on settled commodity contracts were reclassified into cost of materials and other in the condensed consolidated statements of income during both the three and nine months ended September 30, 2018. Losses of $0.7 million and $25.0 million, net of tax, on settled commodity contracts were reclassified into cost of materials and other in the condensed consolidated statements of income during the three and nine months ended September 30, 2017, respectively. We estimate that $3.5 million of deferred losses related to commodity cash flow hedges will be reclassified into cost of materials and other over the next 12 months as a result of hedged transactions that are forecasted to occur.

As of December 31, 2017, gains of $0.4 million, net of tax, related to the interest rate cash flow hedges, remained in accumulated other comprehensive income. Related to Alon's interest rate swap cash flow hedges during the nine months ended September 30, 2018, we recognized $0.1 million and $0.6 million in interest expense on the condensed consolidated statements of income in regards to normal settlements and for early termination settlements reclassified from accumulated other comprehensive income into income as a result of the discontinuation of cash flow hedge accounting, respectively. There was no cash flow hedge ineffectiveness for the nine months ended September 30, 2018 in regards to Alon's interest rate swap cash flow hedges.

Total gains on our trading forward contract derivatives (none of which were designated as hedging instruments) recorded in other operating income (expense), net on the condensed consolidated statements of income are as follows (in millions):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018			2017
Realized gains	$	1.7	$	—	$	10.5	—	$	—
Unrealized gains	3.8		—		6.7			—
Total	$	5.5	$	—	$	17.2		$	—

Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 17 - Commitments and Contingencies

Litigation

In the ordinary conduct of our business, we are from time to time subject to lawsuits, investigations and claims, including environmental claims and employee-related matters. Although we cannot predict with certainty the ultimate resolution of lawsuits, investigations and claims asserted against us, including civil penalties or other enforcement actions, we do not believe that any currently pending legal proceeding or proceedings to which we are a party will have a material adverse effect on our financial statements. Certain environmental matters that have or may result in penalties or assessments are discussed below in the "Environmental, Health and Safety" section of Note 17.

Self-insurance

Delek records a self-insurance accrual for workers’ compensation claims up to a $1.0 million deductible on a per accident basis, general liability claims up to $4.0 million on a per occurrence basis and medical claims for eligible full-time employees up to $0.3 million per covered individual per calendar year. We also record a self-insurance accrual for auto liability up to a $1.0 million deductible on a per accident basis for claims incurred in recent periods, and up to a $4.0 million deductible for remaining claims from certain prior periods.

We have umbrella liability insurance available to each of our segments in an amount determined reasonable by management.

Environmental, Health and Safety

We are subject to extensive federal, state and local environmental and safety laws and regulations enforced by various agencies, including the EPA, the United States Department of Transportation, the Occupational Safety and Health Administration, as well as numerous state, regional and local environmental, safety and pipeline agencies. These laws and regulations govern the discharge of materials into the environment, waste management practices, pollution prevention measures and the composition of the fuels we produce, as well as the safe operation of our plants and pipelines and the safety of our workers and the public. Numerous permits or other authorizations are required under these laws and regulations for the operation of our refineries, renewable fuels facilities, terminals, pipelines, underground storage tanks, trucks, rail cars and related operations, and may be subject to revocation, modification and renewal.

These laws and permits raise potential exposure to future claims and lawsuits involving environmental and safety matters which could include soil and water contamination, air pollution, personal injury and property damage allegedly caused by substances which we manufactured, handled, used, released or disposed of, transported, or that relate to pre-existing conditions for which we have assumed responsibility. We believe that our current operations are in substantial compliance with existing environmental and safety requirements. However, there have been and will continue to be ongoing discussions about environmental and safety matters between us and federal and state authorities, including notices of violations, citations and other enforcement actions, some of which have resulted or may result in changes to operating procedures and in capital expenditures. While it is often difficult to quantify future environmental or safety related expenditures, we anticipate that continuing capital investments and changes in operating procedures will be required for the foreseeable future to comply with existing and new requirements, as well as evolving interpretations and more strict enforcement of existing laws and regulations.

The Big Spring refinery has been negotiating an agreement with the EPA for over 10 years under the EPA’s National Petroleum Refinery Initiative regarding alleged historical violations of the federal Clean Air Act related to emissions and emissions control equipment. A Consent Decree resolving these alleged historical violations for the Big Spring refinery was lodged with the United States District Court for the Northern District of Texas on June 6, 2017, and we expect that Consent Decree with modifications to become final in the fourth quarter of 2018. We anticipate the Consent Decree will require payment of a $0.5 million civil penalty and capital expenditures for pollution control equipment that may be significant over the next five years. While the required capital expenditures may be material, they cannot yet be reasonably estimated until the scope of required equipment is determined.

The Big Spring refinery had been in discussions with the EPA since March 2016 to resolve alleged violations regarding six batches of gasoline produced in 2012-2013 that exceeded the applicable Reid Vapor Pressure standard. The issue, which was previously accrued in the Delek/Alon Merger purchase price allocation, was resolved in January 2018, resulting in payment of a penalty of approximately $0.4 million.

Alon USA’s Paramount Petroleum subsidiary had been in discussions with the State of California since December 2016 regarding alleged violations of the state’s Low Carbon Fuel Standard (“LCFS”) program related to reporting of fuel transactions. The issue, which was previously accrued in the Delek/Alon Merger purchase price allocation, was resolved in March 2018, resulting in payment of a penalty of approximately $0.3 million.

As of September 30, 2018, we have recorded an environmental liability of approximately $143.4 million, primarily related to the estimated probable costs of remediating or otherwise addressing certain environmental issues of a non-capital nature at our refineries, as well as terminals, some of which we no longer own. This liability includes estimated costs for ongoing investigation and remediation efforts, which were already being performed by the former operators of the refineries and terminals prior to our acquisition of those facilities, for known contamination of soil and groundwater, as well as estimated costs for additional issues which have been identified subsequent to the acquisitions. Approximately $7.3 million of the total liability is expected to be expended over the next 12 months, with most of the balance expended by 2032, although some costs may extend up to 30 years. In the future, we could be required to extend the expected remediation period or undertake additional investigations of our refineries, pipelines and terminal facilities, which could result in the recognition of additional remediation liabilities.

Notes to Condensed Consolidated Financial Statements (Unaudited)

We have experienced several crude oil releases from pipelines owned by our logistics segment, including, but not limited to:


•	Magnolia Station in March 2013 (the "Magnolia release")


•	A pipeline segment east of El Dorado, Arkansas in February 2018 (the Sandy Bend - Urbana release)

The United States Department of Justice (the "DOJ"), on behalf of the EPA, and the State of Arkansas, on behalf of the Arkansas Department of Environmental Quality, are currently pursuing an enforcement action against the Partnership with regard to potential violations of the Clean Water Act and certain state laws arising from the Magnolia Release. Although we have been negotiating a resolution to this matter with the EPA and the State of Arkansas, which will include monetary penalties and other relief, the DOJ and the State of Arkansas filed a civil action, on July 13, 2018, against two of Delek Logistics’ wholly-owned subsidiaries, Delek Logistics Operating LLC and SALA Gathering Systems LLC, with regard to the Magnolia Release seeking monetary penalties and injunctive relief. As of September 30, 2018, we have accrued $1.0 million, which we recorded in pipeline release liabilities in our condensed consolidated balance sheet, for the Magnolia Release in connection with these proceedings. We believe this amount is adequate to cover our expected obligations related to these proceedings and that these proceedings will not have a material adverse effect upon Delek's business, financial condition or result of operations.

Letters of Credit

As of September 30, 2018, we had in place letters of credit totaling approximately $143.5 million with various financial institutions securing obligations primarily with respect to our commodity purchases for the refining segment and our workers’ compensation and auto liability insurance programs. No amounts were drawn by beneficiaries of these letters of credit at September 30, 2018.

Note 18 - Employees

Postretirement Benefits

The components of net periodic benefit cost related to our benefit plans consisted of the following:



	Three Months Ended September 30,						Nine Months Ended September 30,
Components of net periodic (benefit) cost:	2018			2017			2018			2017
Service cost	$	0.1		$	1.0		$	0.5		$	1.0
Interest cost	1.3			1.3			3.7			1.3
Expected return on plan assets	(2.1		)	(1.4		)	(5.7		)	(1.4		)
Recognition due to settlement	—			—			(0.1		)	—
Recognition due to curtailment gain	(2.4		)	(6.1		)	(2.4		)	(6.1		)
Net periodic benefit	$	(3.1	)	$	(5.2	)	$	(4.0	)	$	(5.2	)

The service cost component of net periodic benefit is included as part of general and administrative expenses in the accompanying condensed consolidated statements of income. The other components of net periodic benefit are included as part of other non-operating expense (income), net in the accompanying condensed consolidated statements of income. During the nine months ended September 30, 2018, we completely settled the supplemental retirement income plan of the retail segment, and we had a partial settlement of Alon's executive non-qualified restoration plan. During the three months ended September 30, 2018, we entered into an agreement with the International Union of Operating Engineers (the "Union") to extend the Union agreement to March 31, 2022, and to freeze Alon's qualified pension plan for union employees effective July 31, 2018. As part of the extended Union agreement, the Company agreed to compensate each pension-eligible employee in the Union for the loss of the pension benefit over the remaining union contract period in four annual installments, where payments are contingent upon continued employment at each annual payment date. The payments, the first of which was made in July 2018, are expected to total approximately $6.9 million in the aggregate without considering forfeitures (which cannot yet be estimated). The related expense has been or will be recognized over the remaining union contract period as follows (estimated without considering forfeitures): approximately $0.3 million during the three and nine months ended September 30, 2018 and approximately $0.5 million for the remainder of 2018; approximately $2.0 million during each of the years 2019, 2020 and 2021, and approximately $0.1 million in 2022.

Our estimated contributions to our pension plans during 2018 have not changed significantly from amounts previously disclosed in the notes to the consolidated financial statements for the year ended December 31, 2017. For the three and nine months ended September 30, 2018, we made $20.0 million of contributions to our funded qualified pension plan, and we made contributions of a nominal amount and $4.2 million related to payments to participants in our unfunded pension plans for the three and nine months ended September 30, 2018, respectively.

Note 19. Subsequent Events

On November 5, 2018, Alon and certain of its subsidiaries including Alon Bakersfield Property, Inc. (collectively, "ABPI") entered into a Settlement and Release Agreement (the "Settlement Agreement") with Equilon Enterprises, LLC, doing business as Shell Oil Products, US ("Shell"), a former owner of our non-operating refinery located in Bakersfield, California (the "Bakersfield Refinery") which was acquired by Delek in connection with the Delek/Alon Merger. The Settlement Agreement resolved certain disputed indemnification matters related to environmental obligations and asset retirement obligations at the Bakersfield Refinery. As a result of this Settlement Agreement, Shell will pay ABPI a lump sum payment of $34.0 million and convey to APBI ownership of a non-operating terminal located on the site of the Bakersfield Refinery (deemed to have little or no value) and the parties will terminate a nominal lease agreement related to such terminal. Of this total lump sum settlement payment, $14.0 million was previously recognized as an indemnification receivable in the purchase price allocation associated with the Delek/Alon Merger as of July 1, 2017 because such amounts represented indemnification that was deemed by the Company to be probable of realization based on existing indemnification agreements in place on the date of the acquisition and that related to identified asset retirement obligations that were also recognized in the purchase price allocation. The payment is expected to be received in the fourth quarter of 2018 at which point we expect to recognize the benefit of the remaining $20.0 million not previously recognized.

On November 6, 2018, our Board of Directors voted to declare a quarterly cash dividend of $0.26 per share of our common stock, payable on December 4, 2018 to shareholders of record on November 20, 2018. Additionally, on November 6, 2018, the Board of Directors authorized the repurchase of an additional $500.0 million of Delek common stock. This new authorization has no expiration and is in addition to any remaining amounts previously authorized.

On November 9, 2018, Delek entered into a Warrant Unwind Agreement (the "Unwind Agreement") with the holders of our outstanding common stock Warrants (as defined in Note 8). Pursuant to the terms of the Unwind Agreement, we will settle for cash all outstanding Warrants with the holders at various prices per Warrant as provided in the Unwind Agreement. The settlement amount will be based on the volume-weighted average market price of our common stock taking into account an adjustment for the exercise price of the Warrants over a period of sixteen trading days beginning November 9, 2018 (the “Unwind Period”). Following the Unwind Period and upon the satisfaction of the payment obligation, the Warrants will be canceled and the associated rights and obligations terminated. Based on the provisions of the Unwind Agreement, we estimate that the initial liability as of the effective date of the Unwind Agreement is approximately $36 million.

Management's Discussion and Analysis

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Management’s Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") is management’s analysis of our financial performance and of significant trends that may affect our future performance. The MD&A should be read in conjunction with our condensed consolidated financial statements and related notes included elsewhere in this Quarterly Report on Form 10-Q and in the Annual Report on Form 10-K filed with the Securities and Exchange Commission ("SEC") on March 1, 2018 (the "Annual Report on Form 10-K"). Those statements in the MD&A that are not historical in nature should be deemed forward-looking statements that are inherently uncertain.

In January 2017, Delek US Holdings, Inc. ("Old Delek") (and various related entities) entered into an Agreement and Plan of Merger with Alon USA Energy, Inc. (NYSE: ALJ) ("Alon USA") (as amended, the "Merger Agreement"). The related merger (the "Delek/Alon Merger") was effective July 1, 2017 (the “Effective Time”), resulting in a new post-combination consolidated registrant renamed Delek US Holdings, Inc. (“New Delek”), with Alon USA and Old Delek surviving as wholly-owned subsidiaries. New Delek is the successor issuer to Old Delek and Alon USA pursuant to Rule 12g-3(c) under the Securities Exchange Act of 1934, as amended (the "Exchange Act").

Unless otherwise noted or the context requires otherwise, the terms "we," "our," "us," "Delek" and the "Company" are used in this report to refer to Old Delek and its consolidated subsidiaries for the periods prior to July 1, 2017, and New Delek and its consolidated subsidiaries for the periods on or after July 1, 2017 - see Note 1 of the condensed consolidated financial statements in Item 1, Financial Statements, for additional information.

You should read the following discussion of our financial condition and results of operations in conjunction with our historical condensed consolidated financial statements and notes thereto.

Forward-Looking Statements

This Quarterly Report on Form 10-Q contains "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"). These forward-looking statements reflect our current estimates, expectations and projections about our future results, performance, prospects and opportunities. Forward-looking statements include, among other things, the information concerning our possible future results of operations, business and growth strategies, financing plans, expectations that regulatory developments or other matters will or will not have a material adverse effect on our business or financial condition, our competitive position and the effects of competition, the projected growth of the industry in which we operate, and the benefits and synergies to be obtained from our completed and any future acquisitions, statements of management’s goals and objectives, and other similar expressions concerning matters that are not historical facts. Words such as "may," "will," "should," "could," "would," "predicts," "potential," "continue," "expects," "anticipates," "future," "intends," "plans," "believes," "estimates," "appears," "projects" and similar expressions, as well as statements in future tense, identify forward-looking statements.

Forward-looking statements should not be read as a guarantee of future performance or results, and will not necessarily be accurate indications of the times at, or by, which such performance or results will be achieved. Forward-looking information is based on information available at the time and/or management’s good faith belief with respect to future events, and is subject to risks and uncertainties that could cause actual performance or results to differ materially from those expressed in the statements. Important factors that, individually or in the aggregate, could cause such differences include, but are not limited to:


•	volatility in our refining margins or fuel gross profit as a result of changes in the prices of crude oil, other feedstocks and refined petroleum products;


•	our ability to execute our strategy of growth through acquisitions and the transactional risks inherent in such acquisitions;


•	acquired assets may suffer a diminishment in fair value, which may require us to record a write-down or impairment;


•	reliability of our operating assets;


•	competition;


•	changes in, or the failure to comply with, the extensive government regulations applicable to our industry segments;


•	changes in interpretations, assumptions and expectations regarding the Tax Cuts and Jobs Act, including additional guidance that may be issued by federal and state taxing authorities;


•	diminution in value of long-lived assets may result in an impairment in the carrying value of the assets on our balance sheet and a resultant loss recognized in the statement of operations;


•	general economic and business conditions affecting the southern, southwestern and western United States, particularly levels of spending related to travel and tourism;


•	volatility under our derivative instruments;


•	deterioration of creditworthiness or overall financial condition of a material counterparty (or counterparties);

Management's Discussion and Analysis


•	unanticipated increases in cost or scope of, or significant delays in the completion of, our capital improvement and periodic turnaround projects;


•	risks and uncertainties with respect to the quantities and costs of refined petroleum products supplied to our pipelines and/or held in our terminals;


•	operating hazards, natural disasters, casualty losses and other matters beyond our control;


•	increases in our debt levels or costs;


•	changes in our ability to continue to access the credit markets;


•	compliance, or failure to comply, with restrictive and financial covenants in our various debt agreements;


•	the inability of our subsidiaries to freely make dividends, loans or other cash distributions to us;


•	seasonality;


•	acts of terrorism aimed at either our facilities or other facilities that could impair our ability to produce or transport refined products or receive feedstocks;


•	changes in the cost or availability of transportation for feedstocks and refined products; and


•	other factors discussed under the headings "Management’s Discussion and Analysis of Financial Condition and Results of Operations" and "Risk Factors" and in our other filings with the SEC.

In light of these risks, uncertainties and assumptions, our actual results of operations and execution of our business strategy could differ materially from those expressed in, or implied by, the forward-looking statements, and you should not place undue reliance upon them. In addition, past financial and/or operating performance is not necessarily a reliable indicator of future performance, and you should not use our historical performance to anticipate future results or period trends. We can give no assurances that any of the events anticipated by any forward-looking statements will occur or, if any of them do, what impact they will have on our results of operations and financial condition.

Forward-looking statements speak only as of the date the statements are made. We assume no obligation to update forward-looking statements to reflect actual results, changes in assumptions or changes in other factors affecting forward-looking information except to the extent required by applicable securities laws. If we do update one or more forward-looking statements, no inference should be drawn that we will make additional updates with respect thereto or with respect to other forward-looking statements.

Executive Summary and Strategic Overview

Business Overview

We are an integrated downstream energy business focused on petroleum refining, the transportation, storage and wholesale distribution of crude oil, intermediate and refined products and convenience store retailing.

Effective with the Delek/Alon Merger on July 1, 2017, Delek's retail segment includes the operations of Alon's approximately 300 owned and leased convenience store sites located primarily in central and west Texas and New Mexico. These convenience stores typically offer various grades of gasoline and diesel under the Alon brand name and food products, food service, tobacco products, non-alcoholic and alcoholic beverages, general merchandise as well as money orders to the public, primarily under the 7-Eleven and Alon brand names. Substantially all of the motor fuel sold through our retail segment is supplied by our Big Spring refinery, which is transferred to the retail segment at prices substantially determined by reference to published commodity pricing information.

Our corporate activities, results of certain immaterial operating segments, including Alon's asphalt terminal operations effective with the Delek/Alon Merger, our equity method interest in Alon prior to the Delek/Alon Merger, as well as our discontinued Paramount and Long Beach, California refineries and California renewable fuels facility operations (acquired as part of the Delek/Alon Merger - see Note 5 of the condensed consolidated financial statements in Item 1, Financial Statements for further discussion) and intercompany eliminations are reported in the corporate, other and eliminations segment. On March 16, 2018, Delek sold to World Energy, LLC (i) all of Delek’s membership interests in the California renewable fuels facility, (ii) certain refining assets and other related assets located in Paramount, California and (iii) certain associated tank farm and pipeline assets and other related assets located in California, as further discussed in Note 5 of the condensed consolidated financial statements in Item 1, Financial Statements. On May 21, 2018, Delek sold certain assets and operations of four asphalt terminals (included in Delek's corporate/other segment), as well as an equity method investment in an additional asphalt terminal, to an affiliate of Andeavor, as further discussed in Note 5. The transaction to dispose of certain assets and liabilities associated with our Long Beach, California refinery, to Bridge Point Long Beach, LLC, closed July 17, 2018, as further discussed in Note 5.

With respect to asphalt operations, we currently own or operate asphalt terminals located in Big Spring,Texas; Richmond Beach, Washington; and Brownwood, Texas (the Brownwood terminal is 50% owned and recorded under the equity method of accounting). We purchase non-blended asphalt from third parties in addition to non-blended asphalt produced at the Big Spring refinery. We market asphalt through our terminals as blended and non-blended asphalt. Sales of asphalt are seasonal with the majority of sales occurring between May and October.

Management's Discussion and Analysis

The refining segment processes crude oil and other purchased feedstocks for the manufacture of transportation motor fuels, including various grades of gasoline, diesel fuel, aviation fuel, asphalt and other petroleum-based products that are distributed through owned and third-party product terminals. Prior to the Delek/Alon Merger, the refining segment had a combined nameplate capacity of 155,000 bpd, including the 75,000 bpd Tyler, Texas refinery (the "Tyler refinery") and the 80,000 bpd El Dorado, Arkansas refinery (the "El Dorado refinery"). The refining segment also owns and operates two biodiesel facilities involved in the production of biodiesel fuels and related activities, located in Crossett, Arkansas and Cleburn, Texas. Effective with the Delek/Alon Merger, our refining segment now also includes the operations of our refinery located in Big Spring, Texas (the "Big Spring refinery") with a nameplate capacity of 73,000 bpd, a refinery located in Krotz Springs, Louisiana (the "Krotz Springs refinery") with a nameplate capacity of 74,000 bpd and a refinery located in Bakersfield, California. The Bakersfield, California refinery has not processed crude oil since 2012 due to the high cost of crude oil relative to product yield and low asphalt demand. Alon's petroleum-based products are marketed primarily in the south central, southwestern and western regions of the United States and also ships and sells gasoline into wholesale markets in the Southern and Eastern United States. Motor fuels are sold under the Alon brand through various terminals to supply Alon branded retail sites, including our retail segment convenience stores. In addition, Alon sells motor fuels through its wholesale distribution network on an unbranded basis.

Prior to February 7, 2018, we were the majority owner of the Big Spring refinery and its integrated wholesale marketing operations through Alon USA Partners, LP (the "Alon Partnership"). As discussed in Note 3 of the condensed consolidated financial statements in Item 1, Financial Statements, Delek acquired the outstanding limited partner units of the Alon Partnership which Delek did not already own in an all-equity transaction on February 7, 2018. Our marketing of transportation fuels produced at the Big Spring refinery is focused on central and west Texas, Oklahoma, New Mexico and Arizona. We provide substantially all of our branded customers motor fuels, brand support and payment processing services in addition to the license of the Alon brand name and associated trade dress. We market transportation fuel production from our Krotz Springs refinery substantially through bulk sales and exchange channels. These bulk sales and exchange arrangements are entered into with various oil companies and trading companies and are transported to markets on the Mississippi River and the Atchafalaya River, as well as to the Colonial Pipeline.

Our profitability in the refining segment is substantially determined by the difference between the cost of materials and other (including the cost of the crude oil feedstocks we purchase) and the price of the refined products we sell, referred to as the "refining margin" or "refined product margin." Refining margin is used as a metric to assess a refinery's product margins against market crack spread trends, where "crack spread" is a measure of the difference between market prices for crude oil and refined products and is a commonly used proxy within the industry to estimate or identify trends in refining margins. The cost to acquire feedstocks and the price of the refined petroleum products we ultimately sell from our refineries depend on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined petroleum products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions such as hurricanes or tornadoes, local, domestic and foreign political affairs, global conflict, production levels, the availability of imports, the marketing of competitive fuels and government regulation. Other significant factors that influence our results in the refining segment include operating costs (particularly the cost of natural gas used for fuel and the cost of electricity), seasonal factors, refinery utilization rates and planned or unplanned maintenance activities or turnarounds. Moreover, while the fluctuations in the cost of crude oil are typically reflected in the prices of light refined products, such as gasoline and diesel fuel, the price of other residual products, such as asphalt, coke, carbon black oil and liquefied petroleum gas ("LPG"), are less likely to move in parallel with crude cost. This could cause additional pressure on our realized margin during periods of rising or falling crude oil prices. Additionally, our margins are impacted by the pricing differentials of the various types and sources of crude oil we use at our refineries and their relation to product pricing, such as the differentials between West Texas Intermediate ("WTI") Midland and WTI Cushing or WTI Midland and Brent crude oil.

With respect to measuring our refining margins at our refineries, we consider the following:

•

For our Tyler refinery, we compare our per barrel refined product margin to the U.S.Gulf Coast ("Gulf Coast") 5-3-2 crack spread. The Gulf Coast 5-3-2 crack spread is used as a benchmark for measuring a refinery's product margins by measuring the difference between the market price of light products and crude oil, and represents the approximate refining margin resulting from processing five barrels of crude oil into three barrels of gasoline and two barrels of high-sulfur diesel. We calculate the Gulf Coast 5-3-2 crack spread using the market values of Gulf Coast Pipeline CBOB and Gulf Coast Pipeline No. 2 Heating Oil (high-sulfur diesel) and the market value of WTI crude oil. Gulf Coast Pipeline CBOB and Gulf Coast Pipeline No. 2 Heating Oil are prices for which the products trade in the Gulf Coast Region. Gulf Coast Pipeline CBOB is a grade of gasoline commonly blended with biofuels and marketed as Regular Unleaded at retail locations. Gulf Coast Pipeline No. 2 Heating Oil is a petroleum distillate that can be used as either a diesel fuel or a fuel oil. This is the standard by which other distillate products (such as ultra-low sulfur diesel) are priced.

•

For our Big Spring refinery, we compare our per barrel refined product margin to the Gulf Coast 3-2-1 crack spread. The Gulf Coast 3-2-1 crack spread is calculated assuming that three barrels of WTI Cushing crude oil are converted, or cracked, into two barrels of Gulf Coast conventional gasoline and one barrel of Gulf Coast ultra-low sulfur diesel. Our Big Spring refinery is capable of processing substantial volumes of sour crude oil, which has historically cost less than intermediate, and/or substantial volumes of sweet crude oils based on price differentials.

Management's Discussion and Analysis

•

For our Krotz Springs refinery, we compare our per barrel refined product margin to the Gulf Coast 2-1-1 high sulfur diesel crack spread. A Gulf Coast 2-1-1 high sulfur diesel crack spread is calculated assuming that two barrels of Light Louisiana Sweet (“LLS”) crude oil are converted into one barrel of Gulf Coast conventional gasoline and one barrel of Gulf Coast high sulfur diesel. The Krotz Springs refinery has the capability to process substantial volumes of sweet, crude oils to produce a high percentage of refined light products.

•

The crude oil and product slate flexibility of the El Dorado refinery allows us to take advantage of changes in the crude oil and product markets; therefore, we anticipate that the quantities and varieties of crude oil processed and products manufactured at the El Dorado refinery by processing a variety of feedstocks into a number of refined product types will continue to vary. Thus, we do not believe that it is possible to develop a reasonable refined product margin benchmark that would accurately portray our refined product margins at the El Dorado refinery.

A widening of the WTI Cushing less WTI Midland spread will favorably influence the operating margin for our refineries. Alternatively, a narrowing of this differential will have an adverse effect on our operating margins. Global product prices are influenced by the price of Brent crude which is a global benchmark crude. Global product prices influence product prices in the U.S. As a result, our refineries are influenced by the spread between Brent crude and WTI Midland. The Brent less WTI Midland spread represents the differential between the average per barrel price of Brent crude oil and the average per barrel price of WTI Midland crude oil. A widening of the spread between Brent and WTI Midland will favorably influence our refineries' operating margins. Also, the Krotz Springs refinery is influenced by the spread between Brent crude and LLS. The Brent less LLS spread represents the differential between the average per barrel price of Brent crude oil and the average per barrel price of LLS crude oil. A discount in LLS relative to Brent will favorably influence the Krotz Springs refinery operating margin.

Our logistics segment owns and operates crude oil and refined products logistics and marketing assets. The logistics segment generates revenue by charging fees for gathering, transporting and storing crude oil and for marketing, distributing, transporting and storing intermediate and refined products in select regions of the southeastern United States and west Texas for our refining segment and third parties, and effective March 1, 2018, fees related to marketing certain finished products produced at or sold from the Big Spring refinery to various customers (see Note 3 of the condensed consolidated financial statements in Item 1, Financial Statements for further discussion regarding that new marketing agreement).

At September 30, 2018, we own a 61.4% limited partner interest in Delek Logistics Partners, LP ("Delek Logistics") and a 94.6% interest in the entity that owns the entire 2.0% general partner interest in Delek Logistics and all of the incentive distribution rights. Delek Logistics was formed by Delek in 2012 to own, operate, acquire and construct crude oil and refined products logistics and marketing assets. Delek Logistics' initial assets were contributed by us and included certain assets formerly owned or used by certain of our subsidiaries. A substantial majority of Delek Logistics' assets are currently integral to our refining and marketing operations.

The cost to acquire the refined fuel products we sell to our wholesale customers in our logistics segment and at our convenience stores in our retail segment depends on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined petroleum products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, production levels, the availability of imports, the marketing of competitive fuels and government regulation. Our retail merchandise sales are driven by convenience, customer service, competitive pricing and branding. Motor fuel margin is sales less the delivered cost of fuel and motor fuel taxes, measured on a cents per gallon basis. Our motor fuel margins are impacted by local supply, demand, weather, competitor pricing and product brand.

As part of our overall business strategy, we regularly evaluate opportunities to expand our portfolio of businesses and may at any time be discussing or negotiating a transaction that, if consummated, could have a material effect on our business, financial condition, liquidity or results of operations.

2018 Developments

Return to Shareholders

Dividend Declaration

On August 7, 2018, Delek's Board of Directors voted to declare a quarterly cash dividend of $0.25 per share, payable on September 4, 2018, to stockholders of record on August 21, 2018. Our previous quarterly cash dividend amounts were $0.15 per share throughout 2017, $0.20 for the first quarter of 2018, and $0.25 for the second quarter of 2018.

Share Repurchase from Alon Israel/New Share Repurchase Program

On January 23, 2018, Delek repurchased 2.0 million shares of its common stock from Alon Israel in connection with Delek’s rights pursuant to a Stock Purchase Agreement dated April 14, 2015, by and between Delek and Alon Israel. Alon Israel delivered a right of first offer notice to Delek on January 16, 2018, informing Delek of Alon Israel’s intention to sell the 2.0 million shares, and Delek accepted such offer on January 17, 2018. The total purchase price was approximately $75.3 million, or $37.64 per share.

Management's Discussion and Analysis

On February 26, 2018, the Board of Directors approved a new $150.0 million authorization to repurchase Delek common stock, which was announced on February 26, 2018. This amount has no expiration date and is in addition to any remaining amounts previously authorized. The aggregate authorization available as of September 30, 2018 was approximately $67.6 million.

Acquisition of Non-controlling Interest in Alon Partnership

On November 8, 2017, Delek and the Alon Partnership entered into a definitive merger agreement under which Delek agreed to acquire all of the outstanding limited partner units which Delek did not already own in an all-equity transaction. This transaction was approved by all voting members of the board of directors of the general partner of the Alon Partnership upon the recommendation from its conflicts committee and by the board of directors of Delek. This transaction closed on February 7, 2018 (the "Merger Date"). Delek owned approximately 51.0 million limited partner units of the Alon Partnership, or approximately 81.6% of the outstanding units immediately prior to the Merger Date. Under terms of the merger agreement, the owners of the remaining outstanding units in the Alon Partnership that Delek did not currently own immediately prior to the Merger Date received a fixed exchange ratio of 0.49 shares of New Delek common stock for each limited partner unit of the Alon Partnership, resulting in the issuance of approximately 5.6 million shares to the public unitholders of the Alon Partnership. The limited partner interests of the Alon Partnership prior to this acquisition were represented as common units outstanding. Because the transaction represented a combination of ownership interests under common control, the transfer of equity from non-controlling interest to owned interest was recorded at carrying value and no gain or loss was recognized in connection with the transaction.

Sale of Asphalt Assets

On February 12, 2018, Delek announced it had reached a definitive agreement to sell certain assets and operations of four asphalt terminals (included in Delek's corporate/other segment), as well as an equity method investment in an additional asphalt terminal, to an affiliate of Andeavor. This transaction includes asphalt terminal assets in Bakersfield, Mojave and Elk Grove, California and Phoenix, Arizona, as well as Delek’s 50 percent equity interest in the Paramount-Nevada Asphalt Company, LLC joint venture that operates an asphalt terminal located in Fernley, Nevada. On May 21, 2018, Delek completed the transaction and received net proceeds of approximately $110.8 million, inclusive of the $75.0 million base proceeds as well as certain preliminary working capital adjustments. The assets associated with the owned terminals met the definition of held for sale pursuant to ASC 360 as of February 1, 2018, but did not meet the definition of discontinued operations pursuant to ASC 205-20, as the sale of these asphalt assets does not represent a strategic shift that will have a major effect on the entity's operations and financial results. Accordingly, depreciation ceased as of February 1, 2018, and the associated assets to be sold were reclassified to assets held for sale as of that date and were written down to the estimated fair value less costs to sell, resulting in an impairment loss on assets held for sale of $27.5 million for the nine months ended September 30, 2018 (none for the three months ended September 30, 2018). All goodwill associated with the asphalt operations sold was written off in connection with the impairment charge discussed above. In connection with the completion of the sale transaction, we recognized a gain of approximately $13.2 million, resulting from the recognition of certain additional proceeds at closing associated with the asphalt terminals which were not previously determinable/probable and the recognition of the gain on the sale of the joint venture which was not previously recognized as held for sale (as it did not meet the criteria). Such gain on sale of the asphalt assets is reflected in results of continuing operations on the accompanying consolidated income statement. None of these assets met the definition of held for sale pursuant to ASC 360 as of December 31, 2017, and therefore were not reflected as held for sale nor as discontinued operations in the consolidated financial statements as of and for the year ended December 31, 2017.

Disposal of California Discontinued Entities

On March 16, 2018, Delek sold to World Energy, LLC (i) all of Delek’s membership interests in AltAir (ii) certain refining assets and other related assets located in Paramount, California and (iii) certain associated tank farm and pipeline assets and other related assets located in California. Upon final settlement, Delek expects to receive net cash proceeds of approximately $85.9 million, subject to a post-closing working capital settlement, Delek’s portion of the expected biodiesel tax credit for 2017 and certain customary adjustments. The sale resulted in a loss on sale of discontinued operations totaling approximately $41.2 million during the nine months ended September 30, 2018 (none during the three months ended September 30, 2018). Of the total expected proceeds, $70.4 million was received in March 2018 ($14.9 million of which were included in net cash flows from investing activities in discontinued operations), with the remainder expected to be collected upon final settlement. In connection with the sale, the remaining assets and liabilities associated with the sold operations that were not included in the assets and liabilities acquired/assumed by the buyer were reclassified into assets and liabilities held and used (relating to continuing operations) and are presented as such in our September 30, 2018 balance sheet.

The transaction to dispose of certain assets and liabilities associated with our Long Beach, California refinery to Bridge Point Long Beach, LLC, closed July 17, 2018 resulting in initial cash proceeds of approximately $14.5 million, net of expenses.

Management's Discussion and Analysis

Transaction with Delek Logistics

In March 2018, a subsidiary of Delek Logistics completed the acquisition from the Alon Partnership of storage tanks and terminals that support our Big Spring Logistic Assets Acquisition (as defined in Note 3 to our accompanying condensed consolidated financial statements). In addition, a new marketing agreement was entered into between the subsidiary of Delek Logistics and the Alon Partnership pursuant to which the subsidiary of Delek Logistics will provide marketing services for product sales from the Big Spring refinery. The cash paid for the transferred assets was $170.8 million, subject to certain post-closing adjustments, and the cash paid for the marketing agreement was $144.2 million. The transactions were financed with borrowings under the DKL Credit Facility (as defined in Note 8 of the condensed consolidated financial statements in Item 1, Financial Statements).

RINs Waivers

In March 2018, the El Dorado and Krotz Springs refineries both received approval from the EPA for a small refinery exemption from the requirements of the renewable fuel standard for the 2017 calendar year, which resulted in a reduction of our RINs Obligation (as defined in Note 15 to our accompanying condensed consolidated financial statements) and related cost of materials and other of approximately $59.3 million and $31.6 million for the El Dorado and Krotz Springs refineries, respectively, for the nine months ended September 30, 2018.

Delek Revolver and Term Loan

On March 30, 2018, (the "Closing Date"), Delek entered into (i) a new term loan credit agreement with Wells Fargo Bank, National Association, as administrative agent (the "Term Administrative Agent"), Delek, as borrower, and the lenders from time to time party thereto, providing for a senior secured term loan facility in an amount of $700 million (the "Term Loan Credit Facility") and (ii) a second amended and restated credit agreement with Wells Fargo Bank, National Association, as administrative agent (the "Revolver Administrative Agent"), Delek, as borrower, certain subsidiaries of Delek, as guarantors, and the other lenders party thereto, providing for a senior secured asset-based revolving credit facility with commitments of $1.0 billion (the "Revolving Credit Facility" and, together with the "Term Loan Credit Facility," the "New Credit Facilities") - see Note 8 of the condensed consolidated financial statements in Item 1, Financial Statements, for additional information. The Term Loan Credit Facility was drawn in full for $700.0 million on the Closing Date at an original issue discount of 0.50%. Proceeds under the Term Loan Credit Facility, as well as proceeds of approximately $300.0 million in borrowings under the Revolving Credit Facility on the Closing Date, were used to repay certain indebtedness of Delek and its subsidiaries (the “Refinancing”), as well as certain fees, costs and expenses in connection with the closing of the New Credit Facilities, with any remaining proceeds held in cash. Proceeds of future borrowings under the Revolving Credit Facility will be used for working capital and general corporate purposes of Delek and its subsidiaries. We recorded a loss on extinguishment of debt totaling approximately $9.1 million during the nine months ended September 30, 2018 (none during the three months ended September 30, 2018) in connection with the Refinancing.

DKL Notes Offer to Exchange

On April 25, 2018, Delek Logistics made an offer to exchange the 2025 Notes and the related guarantees that were validly tendered and not validly withdrawn for an equal principal amount of exchange notes that are freely tradeable, as required under the terms of the original indenture (the “Exchange Offer”). The Exchange Offer expired on May 23, 2018 (the "Expiration Date"). The terms of the exchange notes that were issued as a result of the Exchange Offer are substantially identical to the terms of the original 2025 Notes.

Settlement of Alon Convertible Notes

On September 17, 2018, Delek settled Alon's Convertible Notes for a combination of cash and shares of Delek common stock. The maturity settlement in respect of the Convertible Notes consisted of (i) cash payments totaling approximately $152.5 million which included a cash payment for outstanding principal of $150.0 million, a cash payment for accrued interest of approximately $2.2 million, a cash payment for dividends of approximately $0.3 million and a nominal cash payment in lieu of fractional shares, and (ii) the issuance of approximately 2.7 million shares of Delek common stock to holders of the Convertible Notes (the “Conversion Shares”). The issuance of the Conversion Shares was made in exchange for the Convertible Notes pursuant to an exemption from the registration requirements provided by Section 3(a)(9) of the Securities Act of 1933, as amended. Also on September 17, 2018, Delek exercised Alon's Call Options in connection with the settlement of the Convertible Notes and received 2.7 million shares of Delek common stock from the Call Option counterparties. On a net basis, the settlement of the Convertible Notes and the exercise of the Call Options resulted in no net dilution to Delek common stock.

Management's Discussion and Analysis

Market Trends

Our results of operations are significantly affected by fluctuations in the prices of certain commodities, including, but not limited to, crude oil, gasoline, distillate fuel, biofuels, natural gas and electricity. Historically, our profitability has been affected by commodity price volatility, specifically as it relates to the price of crude oil and refined products.

The table below reflects the quarterly high, low and average prices of WTI Cushing crude oil for each of the quarterly periods in 2017 and the nine months ended September 30, 2018.

The table below reflects the quarterly high, low and average Gulf Coast 5-3-2 crack spread (Tyler benchmark) for each of the quarterly periods in 2017 and the nine months ended September 30, 2018.

Management's Discussion and Analysis

The table below reflects the quarterly high, low and average Gulf Coast 3-2-1 crack spread (Big Spring benchmark) for each of the quarterly periods in 2017 and the nine months ended September 30, 2018, where we have owned the Big Spring refinery only since the Delek/Alon Merger.

The table below reflects the quarterly high, low and average Gulf Coast 2-1-1 crack spread (Krotz Springs benchmark) for each of the quarterly periods in 2017 and the nine months ended September 30, 2018, where we have owned the Krotz Springs refinery only since the Delek/Alon Merger.

The market price of refined products contributed to the increase in the average Gulf Coast 5-3-2 crack spread to $13.44 during the first nine months of 2018 from $12.46 during the first nine months of 2017, with the Gulf Coast price of gasoline (CBOB) increasing 25.7%, from an average of $1.52 per gallon in the first nine months of 2017 to $1.91 per gallon in the first nine months of 2018 and the Gulf Coast price of High Sulfur Diesel increased 37.1%, from an average of $1.40 per gallon in the first nine months of 2017 to $1.92 per gallon in the first nine months of 2018. The charts below illustrate the quarterly high, low and average prices of Gulf Coast Gasoline, U.S. Gulf Coast High Sulfur Diesel and Ultra Low Sulfur Diesel ("ULSD") for each of the quarterly periods in 2017 and the nine months ended September 30, 2018.

Management's Discussion and Analysis

Management's Discussion and Analysis

As U.S. crude oil production has increased, we have seen the discount for WTI Cushing compared to Brent widen. This generally leads to higher margins in our refineries, as refined product prices are influenced by Brent crude prices and the majority of our crude supply is WTI-linked. The average discount for WTI Cushing compared to Brent increased to $5.81 during the first nine months of 2018 from $3.18 during the first nine months of 2017. We note similar historical trends when reviewing the discount for WTI Cushing compared to LLS, where the discount increased to $4.16 during the first nine months of 2018 from $2.41 during the first nine months of 2017. Additionally, our refineries continue to have relatively greater access to WTI Midland and WTI Midland-linked crude feedstocks compared to certain of our competitors. The average discount for WTI Midland compared to WTI Cushing increased to $7.69 during the first nine months of 2018 from a discount of $0.53 during the first nine months of 2017. As these price discounts increase, so does our competitive advantage, created by our access to WTI Midland-linked crude oil pricing. The chart below illustrates the differentials of both Brent crude oil and WTI Midland crude oil as compared to WTI Cushing crude oil for each of the quarterly periods in 2017 and the nine months ended September 30, 2018.

Management's Discussion and Analysis

Environmental regulations continue to affect our margins in the form of the increasing cost of RINs. On a consolidated basis, we work to balance our RINs Obligations in order to minimize the effect of RINs on our results. While we generate RINs in both our refining and logistics segments through our ethanol blending and biodiesel production, our refining segment needs to purchase additional RINs to satisfy its obligations. As a result, increases in the price of RINs generally adversely affect our results of operations. It is not possible at this time to predict with certainty what future volumes or costs may be, but given the volatile price of RINs, the cost of purchasing sufficient RINs could have an adverse impact on our results of operations if we are unable to recover those costs in the price of our refined products. The chart below illustrates the volatile nature of the price for RINs for each of the quarterly periods in 2017 and the nine months ended September 30, 2018.

Seasonality

Refining Segment

Demand for gasoline and asphalt products is generally higher during the summer months than during the winter months due to seasonal increases in motor vehicle traffic and road and home construction. Varying vapor pressure requirements between the summer and winter months also tighten summer gasoline supply. In addition, our refining segment often performs planned maintenance during the winter, when demand for their products is lower. As a result, our operating results of our refining segment are generally lower for the first and fourth quarters of the calendar year.

Logistics Segment

The volume and throughput of crude oil and refined products transported through our pipelines and sold through our terminals and to third parties is directly affected by the level of supply and demand for all of such products in the markets served directly or indirectly by our assets. Supply and demand for such products fluctuates during the calendar year. Demand for gasoline, for example, is generally higher during the summer months than during the winter months due to seasonal increases in motor vehicle traffic. Varying vapor pressure requirements between the summer and winter months also tighten summer gasoline supply. In addition, our refining segment often performs planned maintenance during the winter, when demand for their products is lower. Accordingly, these factors can diminish the demand for crude oil or finished products by our customers, and therefore limit our volumes or throughput during these periods, and we expect that our operating results will generally be lower during the first and fourth quarters of the calendar year.

Management's Discussion and Analysis

Retail Segment

Demand for gasoline and convenience store merchandise is generally higher during the summer months than during the winter months due to seasonal increases in motor vehicle traffic. As a result, the operating results of our retail segment are generally lower for the first quarter of the calendar year. Weather conditions in our operating area also have a significant effect on our operating results. Customers are more likely to purchase higher profit margin items at our retail fuel and convenience stores, such as fast foods, fountain drinks and other beverages and more gasoline during the spring and summer months. Unfavorable weather conditions during these months and a resulting lack of the expected seasonal upswings in traffic and sales could have a negative impact on our results of operations.

Contractual Obligations

There have been no material changes to our contractual obligations and commercial commitments during the nine months ended September 30, 2018, from those disclosed in our Annual Report on Form 10-K, other than the refinancing of debt (as discussed in Note 8 to the financial statements).

Critical Accounting Policies

The preparation of our consolidated financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and related disclosure of contingent assets and liabilities. The SEC has defined critical accounting policies as those that are both most important to the portrayal of our financial condition and results of operations, and require our most difficult, subjective or complex judgments or estimates. Based on this definition and as further described in our Annual Report on Form 10-K, we believe our critical accounting policies include the following: (i) determining our inventory using the last-in, first-out valuation method for the Tyler refinery, (ii) evaluating impairment for property, plant and equipment and definite life intangibles, (iii) evaluating potential impairment of goodwill, and (iv) estimating environmental expenditures. For all financial statement periods presented, there have been no material modifications to the application of these critical accounting policies or estimates since our most recently filed Annual Report on Form 10-K. See Note 1 of the condensed consolidated financial statements in Item 1, Financial Statements for discussion of updates to our accounting policies.

Non-GAAP Measures

Our management uses certain “non-GAAP” operational measures to evaluate our operating segment performance and non-GAAP financial measures to evaluate past performance and prospects for the future to supplement our GAAP financial information presented in accordance with U.S. GAAP. These financial and operational non-GAAP measures are important factors in assessing our operating results and profitability and include:


•	Refining margin - calculated as the difference between total refining revenues and total cost of materials and other; and


•	Refining margin per throughput barrel - calculated as refining margin divided by our average refining throughput in barrels per day multiplied by 1,000 and multiplied by the number of days in the period.

We believe these non-GAAP operational and financial measures are useful to investors, lenders, ratings agencies and analysts to assess our ongoing performance because, when reconciled to their most comparable GAAP financial measure, they provide improved comparability between periods through the exclusion of certain items that we believe are not indicative of our core operating performance and they may obscure our underlying results and trends.

Non-GAAP measures have important limitations as analytical tools, because they exclude some, but not all, items that affect net earnings and operating income. These measures should not be considered substitutes for their most directly comparable U.S. GAAP financial measures.

The following table provides a reconciliation of refining margin to the most directly comparable U.S.GAAP measure, gross margin:



Refining Segment	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
Net revenues	$	2,375.6	$	2,113.8	$	6,971.3	$	4,366.3
Cost of sales	2,089.9		1,966.9		6,440.6		4,178.3
Gross margin	285.7		146.9		530.7		188.0
Add back (items included in cost of sales):
Operating expenses (excluding depreciation and amortization)	118.8		110.5		346.7		212.9
Depreciation and amortization	33.8		33.2		99.1		76.9
Refining margin	$	438.3	$	290.6	$	976.5	$	477.8

Management's Discussion and Analysis

Summary Financial and Other Information

The following table provides summary financial data for Delek (in millions, except share and per share data):



	Three Months Ended						Nine Months Ended
Statement of Operations Data	September 30,						September 30,
	2018			2017			2018			2017
Net revenues:
Refining⁽¹⁾	$	2,375.6		$	2,113.8		$	6,971.3		$	4,366.3
Logistics	164.1			130.7			498.3			386.9
Retail	246.4			213.9			700.8			213.9
Other⁽¹⁾	(290.9		)	(87.8		)	(758.5		)	(183.7		)
Net revenues	$	2,495.2		$	2,370.6		$	7,411.9		$	4,783.4
Cost of sales:
Cost of materials and other	1,970.5			2,017.2			6,190.1			4,210.7
Operating expenses (excluding depreciation and amortization presented below)	136.4			126.7			400.7			248.5
Depreciation and amortization	41.2			40.1			119.3			93.2
Total cost of sales	2,148.1			2,184.0			6,710.1			4,552.4
Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below)	27.6			26.5			78.9			28.0
General and administrative expenses	58.0			68.0			176.1			122.0
Depreciation and amortization	8.0			6.8			27.1			12.2
Other operating (income) expense, net	(1.7		)	0.7			(9.4		)	1.0
Total operating costs and expenses	2,240.0			2,286.0			6,982.8			4,715.6
Operating income (loss)	255.2			84.6			429.1			67.8
Interest expense	31.2			34.1			95.2			62.5
Interest income	(1.4		)	(0.9		)	(3.0		)	(2.7		)
Income from equity method investments	(4.0		)	(5.1		)	(6.9		)	(9.7		)
Gain on sale of business	—			—			(13.2		)	—
Impairment loss on assets held for sale	—			—			27.5			—
Gain on remeasurement of equity method investment	—			(190.1		)	—			(190.1		)
Loss on extinguishment of debt	0.1			—			9.1			—
Other (income) expense, net	(7.5		)	(5.4		)	(7.9		)	(5.3		)
Total non-operating expenses (income), net	18.4			(167.4		)	100.8			(145.3		)
Income from continuing operations before income tax expense	236.8			252.0			328.3			213.1
Income tax expense	51.0			133.5			66.8			111.5
Income from continuing operations, net of tax	185.8			118.5			261.5			101.6
Income (loss) from discontinued operations, net of tax	0.5			(4.1		)	(8.5		)	(4.1		)
Net income	186.3			114.4			253.0			97.5
Net income attributed to non-controlling interests	6.5			10.0			29.0			19.8
Net income attributable to Delek	$	179.8		$	104.4		$	224.0		$	77.7
Basic income per share:
Income from continuing operations	$	2.15		$	1.35		$	2.89		$	1.20
Income (loss) from discontinued operations	0.01			(0.05		)	(0.20		)	(0.06		)
Total basic income per share	$	2.16		$	1.30		$	2.69		$	1.14
Diluted income per share:
Income from continuing operations	$	2.02		$	1.34		$	2.75		$	1.19
Income (loss) from discontinued operations	0.01			(0.05		)	(0.19		)	(0.06		)
Total diluted income per share	$	2.03		$	1.29		$	2.56		$	1.13

⁽¹⁾The corporate, other and eliminations segment results of operations for the nine months ended September 30, 2018 includes Canada trading activity which was previously included and reported in the refining segment for the three months ended March 31, 2018.

Management's Discussion and Analysis

Results of Operations

Management's Discussion and Analysis

Consolidated Results of Operations — Comparison of the Three Months Ended September 30, 2018 versus the Three Months Ended September 30, 2017 and the Nine Months Ended September 30, 2018 versus the Nine Months Ended September 30, 2017

Net Income

Q3 2018 vs. Q3 2017

Consolidated net income for the third quarter of 2018 was $186.3 million compared to $114.4 million for the third quarter of 2017. Consolidated net income attributable to Delek for the third quarter of 2018 was $179.8 million, or $2.16 per basic share, compared to $104.4 million, or $1.30 per basic share, for the third quarter of 2017. Explanations for significant drivers impacting net income as compared to the comparable period of the prior year are discussed in the sections below.

YTD 2018 vs. YTD 2017

Consolidated net income for the nine months ended September 30, 2018 was $253.0 million compared to $97.5 million for the nine months ended September 30, 2017. Consolidated net income attributable to Delek for the nine months ended September 30, 2018 was $224.0 million, or $2.69 per basic share, compared to $77.7 million, or $1.14 per basic share, for the nine months ended September 30, 2017. Explanations for significant drivers impacting net income as compared to the comparable period of the prior year are discussed in the sections below.

Net Revenues

Q3 2018 vs. Q3 2017

In the third quarters of 2018 and 2017, we generated net revenues of $2,495.2 million and $2,370.6 million, respectively, an increase of $124.6 million, or 5.3%. The increase in net revenues was primarily driven by the following factors:


•	the effects of increases in the price of finished petroleum products at our refineries (including a 35.17% increase in average price of CBOB gasoline per gallon and a 43.5% increase in average price of ULSD per gallon).

Such increases were partially offset by:


•	a decrease in sales volumes in the refining segment (where increases in sales volumes at the Tyler, Big Spring and Krotz Springs refineries were offset by decreases in sales volumes at the El Dorado refinery); and


•	a decrease in sales volumes to third parties in the logistics wholesale business.

YTD 2018 vs. YTD 2017

For the nine months ended September 30, 2018 and 2017, we generated net revenues of $7,411.9 million and $4,783.4 million, respectively, an increase of $2,628.5 million, or 55.0%. The increase in net revenues was primarily driven by the following:


•	the addition of Alon financial results as a result of the Delek/Alon Merger, which contributed net incremental revenues of $1,231.9 million during the nine months ended September 30, 2018, which included nine months of Alon operating results, as compared to the nine months ended September 30, 2017, which included only three months of Alon operating results;


•	the effects of increases in the price of finished petroleum products at our refineries (including a 25.7% increase in average price of CBOB gasoline per gallon and a 32.9% increase in average price of ULSD per gallon); and


•	net increases in sales volumes in all three segments.

Management's Discussion and Analysis

Cost of Materials and Other

Q3 2018 vs. Q3 2017

Cost of materials and other was $1,970.5 million for the third quarter of 2018 compared to $2,017.2 million for the third quarter of 2017, a decrease of $46.7 million, or 2.3%. The net decrease in cost of materials and other was primarily driven by the following:


•	a decrease in sales volumes in the refining segment (where increases in sales volumes at the Tyler, Big Spring and Krotz Springs refineries were more than offset by decreases in sales volumes at the El Dorado refinery);


•	a decrease in sales volumes to third parties in the logistics wholesale business; and


•	a decrease in RIN expense from approximately $29.3 million to $7.7 million, where ethanol RIN prices averaged $0.21 per RIN in third quarter 2018 compared to $0.83 per RIN in the prior year period.

Such decreases were partially offset by:


•	increases in the cost of crude oil feedstocks at the refineries including an increase in the cost of WTI Cushing crude oil from an average of $48.16 per barrel to an average of $69.63, and an increase in the cost of WTI Midland crude oil from an average of $47.37 per barrel to an average of $55.28 during the comparable periods;


•	increases in the cost of refined products in the logistics segment where the average cost per gallon of gasoline and diesel purchased increased $0.38 per gallon and $0.56 per gallon, respectively; and


•	an increase in fuel cost of materials and other attributable to an increase in volume of fuel gallons sold in the retail segment from 54,365 thousand in the third quarter 2017 to 55,996 thousand in the third quarter of 2018, combined with an increase in average cost per gallon of $0.46.

YTD 2018 vs. YTD 2017

Cost of materials and other was $6,190.1 million for the nine months ended September 30, 2018, compared to $4,210.7 million for the nine months ended September 30, 2017, an increase of $1,979.4 million, or 47.0%. The increase in cost of materials and other was primarily driven by the following:


•	the addition of Alon financial results as a result of the Delek/Alon Merger, which contributed net incremental cost of materials and other of $781.7 million during the nine months ended September 30, 2018 which included nine months of Alon operating results, as compared to the nine months ended September 30, 2017, which included only three months of Alon operating results;


•	an increase in the cost of crude oil feedstocks at the refineries including an increase in the cost of WTI Cushing crude oil from an average of $49.31 per barrel to an average of $66.90, and an increase in the cost of WTI Midland crude oil from an average of $48.78 per barrel to an average of $59.21; and


•	an increase in the cost of refined products in the logistics segment where the average cost per gallon of gasoline and diesel purchased increased $0.34 per gallon and $0.52 per gallon, respectively.

Such increases were partially offset by:


•	a reduction in cost of materials and other attributable to RIN waivers received which resulted in an incremental net reduction of such costs as compared to the comparable period in the prior year.

Operating Expenses

Q3 2018 vs. Q3 2017

Operating expenses were $136.4 million for the third quarter of 2018 compared to $126.7 million for the third quarter of 2017, an increase of $9.7 million, or 7.7%. The increase in operating expenses was primarily driven by the following:


•	an increase in outside services at the El Dorado refinery related to pipeline repairs and maintenance;


•	an increase in utilities expense associated with increased throughput at the Tyler, Big Spring and Krotz Springs refineries; and


•	increases in maintenance expenses, variable expenses such as utilities, and professional services fees incurred in the logistics segment.

Management's Discussion and Analysis

YTD 2018 vs. YTD 2017

Operating expenses were $400.7 million for the nine months ended September 30, 2018 compared to $248.5 million for the nine months ended September 30, 2017, an increase of $152.2 million, or 61.2%. The increase in operating expenses was primarily driven by the following:


•	the addition of Alon financial results as a result of the Delek/Alon Merger, which contributed incremental operating expenses of $170.7 million during the nine months ended September 30, 2018, which included nine months of Alon operating results, as compared to the nine months ended September 30, 2017, which included only three months of Alon operating results.

General and Administrative Expenses

Q3 2018 vs. Q3 2017

General and administrative expenses were $58.0 million for the third quarter of 2018 compared to $68.0 million for the third quarter of 2017, a decrease of $10.0 million, or 14.7%. The decrease in general and administrative expense was primarily driven by the following:


•	transaction costs associated with the Delek/Alon Merger during the three months ended September 30, 2017 that did not recur in the current period.

YTD 2018 vs. YTD 2017

General and administrative expenses were $176.1 million and $122.0 million for the nine months ended September 30, 2018 and 2017, respectively, an increase of $54.1 million, or 44.3%. The increase was primarily driven by the following:


•	the addition of Alon as a result of the Delek/Alon Merger, which contributed incremental general and administrative expenses of $29.1 million during the nine months ended September 30, 2018, which included nine months of Alon operating results, as compared to the nine months ended September 30, 2017, which included only three months of Alon operating results;


•	a $16.7 million increase in employee related costs resulting from increases in incentive plan costs and the addition of employees in connection with the integration of the acquisition of Alon; and


•	increases in legal fees related to various transactions (including the Big Spring Logistic Assets Acquisition, debt restructuring and sales of California Discontinued Entities) and increases in information technology expenses related to system upgrades, security and licensing.

Depreciation and Amortization

Q3 2018 vs. Q3 2017

Depreciation and amortization (included in both cost of sales and other operating expenses) was $49.2 million for the third quarter of 2018 compared to $46.9 million for the third quarter of 2017, an increase of $2.3 million, or 4.9%. The increase in depreciation expense was primarily driven by the following:


•	capital expenditures during the intervening period partially offset by disposals of assets and the result of certain assets becoming fully depreciated during the period.

YTD 2018 vs. YTD 2017

Depreciation and amortization was $146.4 million compared to $105.4 million for the nine months ended September 30, 2018 and 2017, respectively, an increase of $41.0 million, or 38.9%. The increase in depreciation expense was primarily driven by the following:

•

the addition of Alon property, plant and equipment of $1,130.3 million and the addition of amortizable intangibles of $56.2 million as a result of the Delek/Alon Merger, combined with the addition of other capital expenditures and acquisitions (net of disposals) completed to date, where such additions contributed $39.5 million in incremental depreciation and amortization during the nine months ended September 30, 2018, which included nine months of Alon operating results, as compared to the nine months ended September 30, 2017, which included only three months of Alon operating results.

Management's Discussion and Analysis

Other Operating (Income) Expense, Net

Q3 2018 vs. Q3 2017

Other operating income increased by $2.4 million in the third quarter of 2018 to $1.7 million compared to expense of $0.7 million in the third quarter of 2017, primarily driven by the following:


•	net gains associated with our crude trading operations in the third quarter of 2018.

YTD 2018 vs. YTD 2017

Other operating income increased by $10.4 million to $9.4 million during the nine months ended September 30, 2018 compared to expense of $1.0 million during the nine months ended September 30, 2017, primarily driven by the following:


•	an increase of $17.2 million related to realized and unrealized gains on trading forward contract derivatives and net of losses of $3.5 million on related hedging derivatives in 2018.

Interest Expense

Q3 2018 vs. Q3 2017

Interest expense decreased by $2.9 million, or 8.5%, to $31.2 million in the third quarter of 2018 compared to $34.1 million in the third quarter of 2017, primarily driven by the following:

•

a decrease in the average effective interest rate of 4.66% in the third quarter of 2018 compared to the third quarter of 2017 (where effective interest rate is calculated as interest expense divided by the net average borrowings/obligations outstanding described below) offset by an increase in net average borrowings outstanding (including the obligations under the supply and offtake agreements which have an associated interest charge) of approximately $1,036.0 million in the third quarter of 2018 (calculated as a simple average of beginning borrowings/obligations and ending borrowings/obligations for the period) compared to the third quarter of 2017. The increased borrowings have been used to help finance significant investments in capital assets/projects as well as repurchases of outstanding common stock, and the improvement in effective interest rate is primarily the result of the Refinancing that occurred on March 30, 2018 that reduced our overall effective interest rate on a significant portion of our long-term borrowings.

YTD 2018 vs. YTD 2017

Interest expense increased by $32.7 million, or 52.3% to $95.2 million in the first nine months of September 30, 2018 compared to $62.5 million in the first nine months of September 30, 2017, primarily driven by the following:

•

an increase in net average borrowings outstanding (including the obligations under the supply and offtake agreements which have an associated interest charge) of approximately $735.0 million (calculated as a simple average of beginning borrowings/obligations and ending borrowings/obligations for the period) in the first nine months of September 30, 2018 compared to the first nine months of September 30, 2017, where a significant driver of the increase in borrowings related to the assumption of debt/obligations in connection with the Delek/Alon Merger.

Results from Equity Method Investments

Q3 2018 vs. Q3 2017

We recognized income of $4.0 million from equity method investments during the third quarter of 2018, compared to $5.1 million for the third quarter of 2017, a decrease of $1.1 million. This decrease was primarily driven by the following:


•	the disposal of an equity method investment associated with the sale of asphalt terminals during the intervening period.

YTD 2018 vs. YTD 2017

During the nine months ended September 30, 2018, we recognized income from equity method investments of $6.9 million, compared to $9.7 million for the nine months ended September 30, 2017. This decrease was primarily driven by the following:


•	the absence of the equity method investment in Alon during the nine months ended September 30, 2018 whereas we recognized our proportionate share of the net income from our investment in Alon of $4.5 million, net of $1.3 million in amortization of the excess of our investment over our equity in the underlying net assets of Alon, for the nine months ended September 30, 2017; and


•	the disposal of an equity method investment associated with the sale of asphalt terminals during the nine months ended September 30, 2018.

Management's Discussion and Analysis

Gain on Remeasurement of Equity Method Investment

Q3 2018 vs. Q3 2017

We recorded a gain of $190.1 million on our equity method investment in Alon in the third quarter of 2017, due to the remeasurement of the investment in connection with the Merger, where the remeasured pre-existing non-controlling interest is included as part of the purchase price consideration in recording the acquisition of Alon, net of the reversal of the accumulated other comprehensive income previously recorded related to the equity method investment in Alon. There was no gain on remeasurement of equity method investment recognized during the third quarter ended September 30, 2018

YTD 2018 vs. YTD 2017

We recorded a gain of $190.1 million on our equity method investment in Alon during the nine months ended September 30, 2017, due to the remeasurement of the investment in connection with the Merger, where the remeasured pre-existing non-controlling interest is included as part of the purchase price consideration in recording the acquisition of Alon, net of the reversal of the accumulated other comprehensive income previously recorded related to the equity method investment in Alon. There was no gain on remeasurement of equity method investment recognized during the nine months ended September 30, 2018.

Other Non-operating Expenses, Net

YTD 2018 vs. YTD 2017

During the nine months ended September 30, 2018, we incurred certain infrequently occurring expenses/charges that were not incurred during the nine months ended September 30, 2017. These included a $9.1 million loss on extinguishment of debt related to the Refinancing and an impairment loss on assets held for sale totaling approximately $27.5 million related to the asphalt assets held for sale. These charges were partially offset by a realized gain on the sale of certain asphalt assets totaling $13.2 million, including a gain on the sale of an asphalt equity method investment. See Notes 5 and 8 of the condensed consolidated financial statements in Item 1, Financial Statements, for additional information.

Income Taxes

Q3 2018 vs. Q3 2017

Under ASC 740, Income Taxes (“ASC 740”), companies are required to apply an estimated annual tax rate to interim period results on a year-to-date basis; however, the estimated annual tax rate should not be applied to interim financial results if a reliable estimate cannot be made. In this situation, the interim tax rate should be based on actual year-to-date results. We used an estimated annual tax rate to record income taxes for the three months ended September 30, 2018, and an actual year-to-date effective tax rate to record income taxes for the three months ended September 30, 2017.

We have accounted for the effects of the comprehensive tax legislation commonly referred to as the Tax Cuts and Jobs Act (the "Tax Reform Act"), using reasonable estimates based on currently available information and our interpretations of the Tax Reform Act. The estimated impact of the Tax Reform Act during the three months ended September 30, 2018 may differ from the final accounting as supplemental legislation, regulatory guidance or evolving technical interpretations become available. These changes could be material to income tax expense.

Income tax expense decreased by $82.5 million in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	pre-tax income of $236.8 million in the third quarter of 2018, as compared to $252.0 million for the third quarter of 2017 combined with the effect of the decrease in our effective tax rate which was 21.5% for the third quarter of 2018, compared to 53.0% for the third quarter of 2017.

◦

The change in our effective tax rate was primarily due to the decrease in Federal income tax rate attributable to continued adjustments to properly consider the impact of the Tax Reform Act (which reduced the U.S. federal corporate tax rate from 35% to 21%) combined with the reversal of the deferred tax asset related to the previous held equity method investment in Alon in the third quarter of 2017.

Management's Discussion and Analysis

YTD 2018 vs. YTD 2017

Under ASC 740, companies are required to apply an estimated annual tax rate to interim period results on a year-to-date basis; however, the estimated annual tax rate should not be applied to interim financial results if a reliable estimate cannot be made. In this situation, the interim tax rate should be based on actual year-to-date results. We used an estimated annual tax rate to record income taxes for the nine months ended September 30, 2018, and an actual year-to-date effective tax rate to record income taxes for the nine months ended September 30, 2017.

We have accounted for the effects of the Tax Reform Act, using reasonable estimates based on currently available information and our interpretations of the Tax Reform Act. The estimated impact of the Tax Reform Act during the nine months ended September 30, 2018 may differ from the final accounting as supplemental legislation, regulatory guidance or evolving technical interpretations become available. These changes could be material to income tax expense.

Income tax expense decreased by $44.7 million in the first nine months of September 30, 2018 compared to the first nine months of September 30, 2017, primarily driven by the following:


•	pre-tax income of $328.3 million compared to $213.1 million for the nine months ended September 30, 2018 and 2017, respectively, offset by the decrease in our effective tax rate which was 20.3% compared to 52.3% for the nine months ended September 30, 2018 and 2017, respectively.

◦

The change in our effective tax rate was primarily due to the following: decrease in Federal income tax rate attributable to continued adjustments to properly consider the impact of the Tax Reform Act (which reduced the U.S. federal corporate tax rate from 35% to 21%), combined with income tax benefit for federal tax credits attributable to the Company’s biodiesel blending operations for 2017 and the reversal of the deferred tax asset related to the previous held equity method investment in Alon in the third quarter of 2017, partially offset by tax expense associated with the impairment of assets held for sale.

Management's Discussion and Analysis

Operating Segments

We report operating results in three reportable segments: refining, logistics and retail. Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each of its reportable segments based on the segment contribution margin.

Refining Segment

The tables and charts below set forth certain information concerning our refining segment operations ($ in millions, except per barrel amounts):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018⁽¹⁾		2017
Net revenues	$	2,375.6	$	2,113.8	$	6,971.3	$	4,366.3
Cost of materials and other	1,937.3		1,823.2		5,994.8		3,888.5
Refining margin	438.3		290.6		976.5		477.8
Operating expenses (excluding depreciation and amortization)	118.8		110.5		346.7		212.9
Contribution margin	$	319.5	$	180.1	$	629.8	$	264.9


⁽¹⁾	The net revenues, cost of materials and other and refining margin for the nine months ended September 30, 2018 excludes Canada trading activity which was previously included and reported in the refining segment for the three months ended March 31, 2018.

Management's Discussion and Analysis



Refining Segment	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
Tyler, TX Refinery	(Unaudited)						(Unaudited)
Days in period	92			92			273			273
Total sales volume (average barrels per day)⁽¹⁾	79,691			77,719			78,497			73,865
Products manufactured (average barrels per day):
Gasoline	40,663			41,986			41,417			39,313
Diesel/Jet	31,659			29,864			30,742			28,474
Petrochemicals, LPG, NGLs	3,199			2,526			2,722			2,625
Other	1,646			1,777			1,718			1,668
Total production	77,167			76,153			76,599			72,080
Throughput (average barrels per day):
Crude Oil	72,845			71,332			71,161			67,213
Other feedstocks	4,713			6,619			5,867			5,981
Total throughput	77,558			77,951			77,028			73,194
Per barrel of sales:
Tyler refining margin	$	19.84		$	13.63		$	13.47		$	8.07
Direct operating expenses	$	3.57		$	3.39		$	3.45		$	3.62
Crude Slate: (% based on amount received in period)
WTI crude oil	82.2		%	83.3		%	80.7		%	80.7		%
East Texas crude oil	17.8		%	16.7		%	18.4		%	18.4		%
Other	—		%	—		%	0.9		%	0.9		%

El Dorado, AR Refinery
Days in period	92			92			273			273
Total sales volume (average barrels per day)⁽²⁾	76,196			84,610			74,400			81,679
Products manufactured (average barrels per day):
Gasoline	30,522			37,471			33,948			37,922
Diesel	24,734			28,610			25,423			27,373
Petrochemicals, LPG, NGLs	1,012			1,776			1,236			1,728
Asphalt	5,313			6,741			5,036			6,671
Other	504			1,050			708			1,018
Total production	62,085			75,648			66,351			74,712
Throughput (average barrels per day):
Crude Oil	65,975			74,733			67,688			74,098
Other feedstocks	(2,197		)	2,755			237			1,915
Total throughput	63,778			77,488			67,925			76,013
Per barrel of sales:
El Dorado refining margin	$	9.21		$	7.48		$	8.89		$	7.94
Direct operating expenses	$	4.79		$	3.68		$	4.92		$	3.58
Crude Slate: (% based on amount received in period)
WTI crude oil	68.3		%	62.3		%	66.2		%	63.4		%
Local Arkansas crude oil	20.2		%	19.0		%	20.6		%	18.9		%
Other	11.5		%	18.7		%	13.2		%	17.7		%

Management's Discussion and Analysis



Refining Segment (continued)	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
Big Spring, TX Refinery (acquired on July 1, 2017)	(Unaudited)						(Unaudited)
Days in period	92			92			273			92
Total sales volume (average barrels per day)⁽³⁾	78,062			74,362			72,669			74,362
Products manufactured (average barrels per day):
Gasoline	37,587			35,990			34,931			35,990
Diesel/Jet	29,177			27,001			25,864			27,001
Petrochemicals, LPG, NGLs	3,889			3,861			3,585			3,861
Asphalt	1,713			1,213			1,808			1,213
Other	1,504			1,291			1,366			1,291
Total production	73,870			69,356			67,554			69,356
Throughput (average barrels per day):
Crude oil	72,689			69,117			66,223			69,117
Other feedstocks	828			716			947			716
Total throughput	73,517			69,833			67,170			69,833
Per barrel of sales:
Big Spring refining margin	$	22.20		$	11.71		$	16.73		$	11.71
Direct operating expenses	$	3.78		$	3.88		$	4.12		$	3.88
Crude Slate: (% based on amount received in period)
WTI crude oil	75.4		%	75.4		%	72.7		%	75.4		%
WTS crude oil	24.6		%	24.6		%	27.3		%	24.6		%

Krotz Springs, LA Refinery (acquired on July 1, 2017)
Days in period	92			92			273			92
Total sales volume (average barrels per day) ⁽⁴⁾	76,353			71,129			77,667			71,129
Products manufactured (average barrels per day):
Gasoline	33,103			32,383			36,028			32,383
Diesel/Jet	30,428			27,994			31,161			27,994
Heavy Oils	1,031			978			1,243			978
Petrochemicals, LPG, NGLs	6,531			6,765			7,188			6,765
Total production	71,093			68,120			75,620			68,120
Throughput (average barrels per day):
Crude Oil	71,746			68,998			73,410			68,998
Other feedstocks	(1,552		)	(706		)	1,072			(706		)
Total throughput	70,194			68,292			74,482			68,292
Per barrel of sales:
Krotz Springs refining margin	$	10.41		$	8.18		$	8.70		$	8.18
Direct operating expenses	$	3.98		$	4.08		$	3.80		$	4.08
Crude Slate: (% based on amount received in period)
WTI Crude	71.6		%	46.3		%	62.1		%	46.3		%
Gulf Coast Sweet Crude	28.4		%	53.7		%	37.9		%	53.7		%

Management's Discussion and Analysis



Pricing statistics (average for the period presented):	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
	(Unaudited)				(Unaudited)

WTI — Cushing crude oil (per barrel)	$	69.63	$	48.16	$	66.90	$	49.31
WTI — Midland crude oil (per barrel)	$	55.28	$	47.37	$	59.21	$	48.78
WTS -- Midland crude oil (per barrel) ⁽⁵⁾	$	55.36	$	47.19	$	58.76	$	48.16
LLS (per barrel) ⁽⁵⁾	$	74.14	$	51.62	$	71.06	$	51.72
Brent crude oil (per barrel)	$	75.76	$	52.21	$	72.71	$	52.49

U.S. Gulf Coast 5-3-2 crack spread (per barrel) ⁽⁵⁾	$	14.33	$	15.92	$	13.44	$	12.46
U.S. Gulf Coast 3-2-1 crack spread (per barrel) ⁽⁵⁾	$	17.43	$	20.16	$	17.02	$	16.20
U.S. Gulf Coast 2-1-1 crack spread (per barrel) ⁽⁵⁾	$	11.20	$	13.63	$	10.59	$	11.30

U.S. Gulf Coast Unleaded Gasoline (per gallon)	$	1.98	$	1.58	$	1.91	$	1.52
Gulf Coast Ultra low sulfur diesel (per gallon)	$	2.14	$	1.62	$	2.06	$	1.55
U.S. Gulf Coast high sulfur diesel (per gallon)	$	2.03	$	1.44	$	1.92	$	1.40
Natural gas (per MMBTU)	$	2.86	$	2.95	$	2.85	$	3.05

⁽¹⁾

Total sales volume includes 608 bpd sold to the logistics segment during the nine months ended September 30, 2018, and 869 and 851 during the three and nine months ended September 30, 2017, respectively. Total sales volume also includes sales of 365 and 203 bpd of intermediate and finished products to the El Dorado refinery during the three and nine months ended September 30, 2018, respectively, and 350 and 121 bpd during the three and nine months ended September 30, 2017, respectively. Total sales volume also includes 398 and 438 bpd of produced finished product sold to the Big Spring refinery and 211 and 150 bpd sold to the Krotz Springs refinery during the three and nine months ended September 30, 2018, respectively. Total sales volume excludes 5,218 and 4,589 bpd of wholesale activity during the three and nine months ended September 30, 2018, respectively, and 3,038 and 4,536 of wholesale activity during the three and nine months ended September 30, 2017, respectively.

⁽²⁾

Total sales volume includes 6,939 and 7,114 bpd of produced finished product sold to the Tyler refinery during the three and nine months ended September 30, 2018, respectively, and 460 and 674 bpd during the three and nine months ended September 30, 2017, respectively; 41,076 and 21,822 bpd of produced finished product sold to the Krotz Springs refinery during the three and nine months ended September 30, 2018, respectively; 57 and 395 bpd of produced finished product sold to the Big Spring refinery during the three and nine months ended September 30, 2018, respectively; 194 bpd of produced finished product sold to logistics segment during the nine months ended September 30, 2018, and 1,191 and 415 bpd during the three and nine months ended September 30, 2017, respectively; 167 and 273 bpd of produced finished product sold to the retail segment during the three and nine months ended September 30, 2018, respectively; and 51 and 112 bpd of produced finished product sold to Alon Asphalt Company during the three and nine months ended September 30, 2018, respectively. Total sales volume excludes 45,928 and 49,098 bpd of wholesale activity during the three and nine months ended September 30, 2018, respectively, and 23,917 and 19,726 bpd of wholesale activity during the three and nine months ended September 30, 2017, respectively.


⁽³⁾	Total sales volume includes 14,457 and 14,171 bpd sold to the retail segment, 871 and 3,103 bpd sold to the logistics segment and 1,706 and 1,584 bpd sold to Alon Asphalt Company during the three and nine months ended September 30, 2018, respectively.


⁽⁴⁾	Sales volume includes 38,766 and 32,671 bpd sold to the El Dorado refinery and 2,356 and 867 bpd sold to the Tyler refinery during the three and nine months ended September 30, 2018, respectively.

⁽⁵⁾

For our Tyler and El Dorado refineries, we compare our per barrel refining product margin to the Gulf Coast 5-3-2 crack spread consisting of WTI Cushing crude, U.S. Gulf Coast CBOB and U.S, Gulf Coast Pipeline No. 2 heating oil (high sulfur diesel). For our Big Spring refinery, we compare our per barrel refined product margin to the Gulf Coast 3-2-1 crack spread consisting of WTI Cushing crude, Gulf Coast 87 Conventional gasoline and Gulf Coast ultra low sulfur diesel, and for our Krotz Springs refinery, we compare our per barrel refined product margin to the Gulf Coast 2-1-1 crack spread consisting of LLS crude oil, Gulf Coast 87 Conventional gasoline and U.S, Gulf Coast Pipeline No. 2 heating oil (high sulfur diesel). The Tyler refinery's crude oil input is primarily WTI Midland and east Texas, while the El Dorado refinery's crude input is primarily combination of WTI Midland, local Arkansas and other domestic inland crude oil. The Big Spring refinery’s crude oil input is primarily comprised of WTS and WTI Midland. The Krotz Springs refinery’s crude oil input is primarily comprised of LLS and WTI Midland. The Big Spring and Krotz Springs refineries were acquired July 1, 2017 as part of the Delek/Alon Merger, so Gulf Coast 3-2-1 and 2-1-1 crack spreads, LLS and WTS statistics are presented only for the period Delek owned these refineries.

Management's Discussion and Analysis

Refining Segment Operational Comparison of the Three Months Ended September 30, 2018 versus the Three Months Ended September 30, 2017 and the Nine Months Ended September 30, 2018 versus the Nine Months Ended September 30, 2017

Net Revenues

Q3 2018 vs. Q3 2017

Net revenues for the refining segment increased by $261.8 million, or 12.4%, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	increases in the price of U.S. Gulf Coast gasoline, ULSD, and High-Sulfur diesel ("HSD"), where increases in sales volume at the Tyler, Big Spring and Krotz Springs refineries were offset by a decrease in sales volume at El Dorado refinery.

YTD 2018 vs. YTD 2017

Net revenues for the refining segment increased by $2,605.0 million, or 59.7%, in the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017, primarily driven by the following:


•	the addition of the Big Spring and Krotz Springs refineries in connection with the Delek/Alon Merger on July 1, 2017; and


•	increases in the price of both U.S. Gulf Coast gasoline, ULSD and HSD.

Management's Discussion and Analysis

Cost of Materials and Other

Q3 2018 vs. Q3 2017

Cost of materials and other increased by $114.1 million, or 6.3%, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	an increase in sales volumes at the Tyler, Big Spring and Krotz Springs refineries, offset by a decrease in sales volumes at the El Dorado refinery;


•	an increase in the cost of WTI Cushing crude oil, from an average of $48.16 per barrel to an average of $69.63; and


•	an increase in the cost of WTI Midland crude oil, from an average of $47.37 per barrel to an average of $55.28.

This increase was partially offset by the following:


•	a decrease in RIN expense from approximately $29.3 million to $7.7 million, where ethanol RIN prices averaged $0.21 per RIN in third quarter 2018 compared to $0.83 per RIN in the prior year period.

YTD 2018 vs. YTD 2017

Cost of materials and other increased by $2,106.3 million, or 54.2%, in the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017, primarily driven by the following:


•	the addition of the Big Spring and Krotz Springs refineries in connection with the Delek/Alon Merger on July 1, 2017;


•	an increase in the cost of WTI Cushing crude oil from an average of $49.31 per barrel to an average of $66.90; and


•	an increase in the cost of WTI Midland crude oil, from an average of $48.78 per barrel to an average of $59.21.

This increase was partially offset by the following:

•

a reduction of our RINs Obligation and related cost of materials and other of approximately $59.3 million and $47.5 million for the nine months ended September 30, 2018 and 2017, respectively, related to the receipt of small refinery exemptions from the requirements of the renewable fuel standard at our El Dorado refinery for the 2017 and 2016 calendar years, respectively. In March 2018, the Krotz Springs refinery received such approval as well, which resulted in a reduction of our RINs Obligation and related cost of materials and other of approximately $31.6 million for the nine months ended September 30, 2018.

Our refining segment has multiple service agreements with our logistics segment which, among other things, require the refining segment to pay terminalling and storage fees based on the throughput volume of crude and finished product in the logistics segment pipelines and the volume of crude and finished product stored in the logistics segment storage tanks, subject to minimum volume commitments. These fees were $54.1 million and $33.5 million during the third quarters of 2018 and 2017, respectively and $152.0 million and $97.7 million during the nine months ended September 30, 2018 and 2017, respectively. We eliminate these intercompany fees in consolidation.

Management's Discussion and Analysis

Refining Margin

Q3 2018 vs. Q3 2017

Refining margin increased by $147.7 million, or 50.8%, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:

•

wider discounts between WTI Cushing crude oil compared to Brent and WTI Midland crude oil compared to WTI Cushing which impact refining margin at the Tyler and El Dorado Refineries where, during the third quarter of 2018, the average WTI Cushing crude oil differential to Brent crude oil was $6.13 per barrel compared to $4.05 during the third quarter of 2017, and the average WTI Midland crude oil differential to WTI Cushing crude oil was $14.35 per barrel compared to $0.79 during the third quarter of 2017;

•

wider discounts between WTI Cushing and WTS and LLS crude oil which impact refining margin at the Big Spring and Krotz Springs Refineries where, during the third quarter of 2018, the average WTI Cushing crude oil differential to WTS crude oil was $14.27 per barrel compared to $0.97 during the third quarter of 2017, and the average WTI Cushing crude oil differential to LLS crude oil was $4.51 per barrel compared to $3.46 during the third quarter of 2017;


•	a wider discount between Midland WTI crude oil and Brent crude oil where, during the third quarter of 2018, the Midland WTI crude oil differential to Brent crude oil was an average discount of $20.48 per barrel compared to $4.84 per barrel during the third quarter of 2017; and


•	the cost of materials and other benefit attributable to the decrease in RIN prices.

These increases were partially offset by the following:


•	a 10.0% decline in the average Gulf Coast 5-3-2 crack spread (the primary measure for the Tyler Refinery), as well as declines in the average Gulf Coast 3-2-1 crack spread (the primary measure for the Big Spring Refinery) and average Gulf Coast 2-1-1 crack spread (the primary measure for the Krotz Springs Refinery).

Management's Discussion and Analysis

YTD 2018 vs. YTD 2017

Refining margin increased by $498.7 million or 104.4%, in the first nine months of September 30, 2018 compared to the first nine months of September 30, 2017, with a refining margin percentage of 14.0% as compared to 10.9% for the nine months ended September 30, 2018 and 2017, respectively, primarily driven by the following:


•	the addition of the Big Spring and Krotz Springs refineries in connection with the Delek/Alon Merger on July 1, 2017;

•

wider discounts between WTI Cushing crude oil compared to Brent and WTI Midland crude oil compared to WTI Cushing which impact refining margin at the Tyler and El Dorado Refineries where, during the nine months ended September 30, 2018 the average WTI Cushing crude oil differential to Brent crude oil was $5.81 per barrel compared to $3.18 during the nine months of September 30, 2017, and the average WTI Midland crude oil differential to WTI Cushing crude oil was $7.69 per barrel compared to $0.53 during the nine months of September 30, 2017;


•	a 7.9% improvement in the average Gulf Coast 5-3-2 crack spread; and


•	the cost of materials and other benefit attributable to the RIN waivers.

Management's Discussion and Analysis

Operating Expenses

Q3 2018 vs. Q3 2017

Operating expenses increased by $8.3 million, or 7.5%, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	an increase in outside services at the El Dorado refinery related to pipeline repairs and maintenance; and


•	an increase in utilities expense associated with increased throughput at the Tyler, Big Spring and Krotz Springs refineries.

YTD 2018 vs. YTD 2017

Operating expenses increased by $133.8 million, or 62.8%, in the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017, primarily driven by the following:


•	the addition of the Big Spring and Krotz Springs refineries in connection with the Delek/Alon Merger on July 1, 2017.

Contribution Margin

Q3 2018 vs. Q3 2017

Contribution margin increased by $139.4 million, or a 5.9% improvement in contribution margin percentage, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	a wider discount between Midland WTI crude oil and Brent crude oil where, during the third quarter of 2018, the Midland WTI crude oil differential to Brent crude oil was an average discount of $20.48 per barrel compared to $4.84 per barrel in the prior-year period as well as favorability in the other crude differentials impacting our refineries described above; and


•	the cost of materials and other benefit attributable to the decrease in RIN prices.

These increases were partially offset by the following:


•	a 10.0% decline in the average Gulf Coast 5-3-2 crack spread as well as declines in the other relevant crack spreads described above.

YTD 2018 vs. YTD 2017

Contribution margin increased by $364.9 million, or a 3.7% improvement in contribution margin percentage, in the first nine months of September 30, 2018 compared to the first nine months of September 30, 2017, primarily driven by the following:


•	the addition of the Big Spring and Krotz Springs refineries in connection with the Delek/Alon Merger on July 1, 2017;


•	a 7.9% improvement in the average Gulf Coast 5-3-2 crack spread;


•	improvements in crude oil differentials as described above; and


•	the cost of materials and other benefit attributable to the RIN waivers.

Management's Discussion and Analysis

Logistics Segment

The table below sets forth certain information concerning our logistics segment operations ($ in millions, except per barrel amounts):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
Logistics Segment Contribution:
Net revenues	$	164.1	$	130.7	$	498.3	$	386.9
Cost of materials and other	105.6		89.1		330.6		266.7
Operating expenses (excluding depreciation and amortization)	15.4		10.7		42.9		31.0
Contribution margin	$	43.1	$	30.9	$	124.8	$	89.2

Operating Information:
East Texas - Tyler Refinery sales volumes (average bpd)⁽¹⁾	79,404		74,357		77,349		71,917
West Texas wholesale marketing throughputs (average bpd)	12,197		12,929		13,453		13,647
West Texas wholesale marketing margin per barrel	$	4.65	$	4.00	$	5.88	$	3.62
Big Spring wholesale marketing throughputs (average bpd) ⁽²⁾	80,687		—		79,819		—
Terminalling throughputs (average bpd) ⁽³⁾	167,491		127,229		159,457		123,780
Throughputs (average bpd)
Lion Pipeline System:
Crude pipelines (non-gathered)	59,150		60,247		56,672		59,653
Refined products pipelines to Enterprise Systems	43,762		51,623		47,154		50,933
SALA Gathering System	16,704		15,997		16,705		16,160
East Texas Crude Logistics System	14,284		15,260		16,402		15,006


⁽¹⁾	Excludes jet fuel and petroleum coke.


⁽²⁾	Throughputs for the nine months ended September 30, 2018 are for the 214 days we marketed certain finished products produced at or sold from the Big Spring Refinery following the execution of the Big Spring Marketing Agreement, effective March 1, 2018, as defined in Note 3 to our accompanying condensed consolidated financial statements.

⁽³⁾

Consists of terminalling throughputs at our Tyler, Big Spring, Big Sandy and Mount Pleasant, Texas, our El Dorado and North Little Rock, Arkansas and our Memphis and Nashville, Tennessee terminals. Throughputs for the nine months ended September 30, 2018 for the Big Spring terminal are for the 214 days we operated the terminal following its acquisition effective March 1, 2018. Barrels per day are calculated for only the days we operated each terminal. Total throughput barrels for the nine months ended September 30, 2018 was 41.4 million barrels, which averaged 151,646 bpd for the period.

Management's Discussion and Analysis

Logistics Segment Operational Comparison of the Three Months Ended September 30, 2018 versus the Three Months Ended September 30, 2017 and the Nine Months Ended September 30, 2018 versus the Nine Months Ended September 30, 2017

Net Revenues

Q3 2018 vs. Q3 2017

Net revenues increased by $33.4 million, or 25.6%, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	net revenues generated under the agreements executed in connection with the Big Spring Logistic Assets Acquisition, which were effective March 1, 2018. Refer to Note 3 to our accompanying condensed consolidated financial statements for additional information about the agreements executed in connection with the Big Spring Logistic Assets Acquisition; and


•	increases in the average sales prices per gallon of gasoline and diesel sold in our west Texas marketing operations. The average sales prices per gallon of gasoline and diesel sold increased $0.42 per gallon and $0.55 per gallon, respectively; and

Net revenues included $9.0 million and $5.2 million of net service fees paid by our refining segment to our logistics segment during the third quarter of 2018 and 2017, respectively. These service fees are based on the number of gallons sold and a fee for providing sales and customer support services. Net revenues also included crude and refined product transportation, terminalling and storage fees paid by our refining segment to our logistics segment, which includes revenues earned under the commercial agreements entered into in connection with the Big Spring Logistic Assets Acquisition. These fees were $54.1 million and $33.5 million in the third quarter of 2018 and 2017, respectively. The logistics segment also sold $0.3 million and $1.4 million of RINs to the refining segment during the third quarter of 2018 and 2017, respectively. These intercompany sales and fees are eliminated in consolidation.

YTD 2018 vs. YTD 2017

Net revenues increased by $111.4 million, or 28.8%, in the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017 primarily driven by the following:


•	increases in the average sales prices per gallon of gasoline and diesel sold in our west Texas marketing operations. The average sales prices per gallon of gasoline and diesel sold increased $0.42 per gallon and $0.56 per gallon, respectively;


•	net revenues generated under the agreements executed in connection with the Big Spring Logistics Assets Acquisition, which were effective March 1, 2018. Refer to Note 3 to our accompanying condensed consolidated financial statements for additional information about the agreements executed in connection with the Big Spring Logistic Assets Acquisition; and


•	increased net revenue related to the Paline Pipeline as a result of volume increases on the pipeline.

Net revenues included $23.8 million and $14.8 million of net service fees paid by our refining segment to our logistics segment during the nine months ended September 30, 2018 and 2017, respectively. These service fees are based on the number of gallons sold and a shared portion of the margin achieved in return for providing sales and customer support services. Net revenues also included crude and refined product transportation, terminalling and storage fees paid by our refining segment to our logistics segment, which includes revenues earned under the commercial agreements entered into in connection with the Big Spring Logistic Assets Acquisition. These fees were $152.0 million and $97.7 million in the nine months ended September 30, 2018 and 2017, respectively. The logistics segment also sold $2.3 million and $3.9 million of RINs to the refining segment in the nine months ended September 30, 2018 and 2017, respectively. These intercompany sales and fees are eliminated in consolidation.

Management's Discussion and Analysis

Cost of Materials and Other

Q3 2018 vs. Q3 2017

Cost of materials and other for the logistics segment increased $16.5 million, or 18.5%, in the third quarter of 2018 compared to the third quarter of 2017. This increase was primarily driven by the following:


•	increases in the average cost per gallon of gasoline and diesel purchased in our west Texas marketing operations. The average cost per gallon of gasoline and diesel purchased increased $0.38 per gallon and $0.56 per gallon, respectively.

YTD 2018 vs. YTD 2017

Cost of materials and other for the logistics segment increased $63.9 million, or 24.0%, in the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017. This increase was primarily driven by the following:


•	increases in the average cost per gallon of gasoline and diesel purchased in our west Texas marketing operations. The average cost per gallon of gasoline and diesel purchased increased $0.34 per gallon and $0.52 per gallon, respectively.

Operating Expenses

Q3 2018 vs. Q3 2017

Operating expenses increased by $4.7 million, or 43.9%, in the third quarter of 2018 compared to the third quarter of 2017, driven by the following:


•	higher operating costs associated with the logistics assets acquired in the Big Spring Logistic Assets Acquisition, including maintenance expenses, allocated employee costs, variable expenses such as utilities, and professional services fees incurred in connection with the transaction; and


•	higher employee costs, primarily payroll expense, allocated to the logistics segment as a result of an increase in allocated employee headcount.

YTD 2018 vs. YTD 2017

Operating expenses increased by $11.9 million, or 38.4%, in the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017, primarily driven by the following:


•	higher operating costs associated with the assets acquired in the Big Spring Logistic Asset Acquisition, including including maintenance expenses, allocated employee costs, variable expenses such as utilities, and professional services fees incurred in connection with the transaction; and


•	higher employee costs allocated to the logistics segment as a result of increases in allocated employee headcount and employee incentive costs.

Management's Discussion and Analysis

Contribution Margin

Q3 2018 vs. Q3 2017

Contribution margin increased by $12.2 million, or 39.5%, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	improved contribution margin in our west Texas operations as a result of continued increased drilling activity in the region and favorable market price movements; and


•	increases in revenue generated under the agreements executed in connection with the Big Spring Logistic Assets Acquisition as described above.

YTD 2018 vs. YTD 2017

Contribution margin increased by $35.6 million, or 39.9%, in the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017, primarily driven by the following:


•	improved contribution margin in our west Texas operations as a result of continued increased drilling activity in the region and favorable market price movements; and


•	increases in revenue generated under the agreements executed in connection with the Big Spring Logistic Assets Acquisition as described above.

Management's Discussion and Analysis

Retail Segment

The Retail Segment was not reported for the periods prior to July 1, 2017 (the date of the Delek/Alon Merger which included the Retail Segment). The table below sets forth certain information concerning our retail segment operations (gross sales $ in millions):



	Three Months Ended September 30,						Nine Months Ended September 30,
	2018			2017			2018			2017
Net revenues	$	246.4		$	213.9		$	700.8		$	213.9
Cost of materials and other	204.4			174.6			578.5			174.6
Operating expenses (excluding deprecation and amortization)	26.7			25.8			76.5			25.8
Contribution margin	$	15.3		$	13.5		$	45.8		$	13.5
Operating Information:
Number of stores (end of period)	295			302			295			302
Average number of stores	295			302			295			302
Retail fuel sales	$	154.2		$	123.5		$	435.2		$	123.5
Retail fuel sales (thousands of gallons)	55,996			54,365			163,809			54,365
Average retail gallons per average number of stores (in thousands)	196			186			573			186
Average retail sales price per gallon sold	$	2.75		$	2.27		$	2.66		$	2.27
Retail fuel margin ($ per gallon) ⁽¹⁾	$	0.23		$	0.20		$	0.22		$	0.20
Merchandise sales	$	89.7		$	91.3		$	258.0		$	91.3
Merchandise sales per average number of stores	$	0.3		$	0.3		$	0.9		$	0.3
Merchandise margin %	31.3		%	31.4		%	31.1		%	31.4		%



	Three Months Ended September 30, 2018
Change in same-store fuel gallons sold	4.4	%
Change in same-store fuel sales	26.7	%
Change in same-store merchandise sales	3.7	%


⁽¹⁾	Retail fuel margin represents gross margin on fuel sales in the retail segment, and is calculated as retail fuel sales revenue less retail fuel cost of sales. The retail fuel margin per gallon calculation is derived by dividing retail fuel margin by the total retail fuel gallons sold for the period.

Management's Discussion and Analysis

Retail Segment Operational Comparison of the Three Months Ended September 30, 2018 versus the Three Months Ended September 30, 2017 and the Nine Months Ended September 30, 2018 versus the Nine Months Ended September 30, 2017

Net Revenues

Q3 2018 vs. Q3 2017

Net revenues for the retail segment increased by $32.5 million, or 15.2%, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	retail fuel gallons sold for the retail segment were 55,996 thousand gallons in the third quarter of 2018 compared to 54,365 thousand gallons in the third quarter of 2017 with same-store sales growth in fuel volumes of 4.4%; and


•	total fuel sales were $154.2 million in the third quarter of 2018 compared to $123.5 million in the third quarter of 2017 as a result of the increase in gallons sold combined with a $0.48 increase in average price charged per gallon (as indicated by the same-store fuel sales increase of 26.7% as compared to the same-store fuel gallons sold increase of 4.4%).

Such increase was partially offset by the following:


•	merchandise sales were $89.7 million in the third quarter of 2018 compared to $91.3 million in the third quarter of 2017 which included a same-store sales increase of 3.7% offset by the reduction in average number of stores period over period.

YTD 2018 vs. YTD 2017

Net revenues for the retail segment increased by $486.9 million, or 227.6% in the first nine months of September 30, 2018 compared to the first nine months of September 30, 2017, primarily driven by the following:


•	the addition of approximately 300 convenience stores on July 1, 2017 in connection with the Delek/Alon Merger.

Management's Discussion and Analysis

Cost of Materials and Other

Q3 2018 vs. Q3 2017

Cost of materials and other for the retail segment increased by $29.8 million, or 17.1%, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	an increase in fuel cost of materials and other attributable to an increase in volume of fuel gallons sold from 54,365 thousand in the third quarter 2017 to 55,996 thousand in the third quarter of 2018, combined with an increase in average cost per gallon of $0.46.

YTD 2018 vs. YTD 2017

Cost of materials and other for the retail segment increased by $403.9 million, or 231.3%, in the first nine months of September 30, 2018 compared to the first nine months of September 30, 2017, primarily driven by the following:


•	the addition of approximately 300 convenience stores on July 1, 2017 in connection with the Delek/Alon Merger.

Operating Expenses

Q3 2018 vs. Q3 2017

Operating expenses for the retail segment increased by $0.9 million, or 3.5% in the third quarter of 2018 compared to the third quarter of 2017.

YTD 2018 vs. YTD 2017

Operating expenses for the retail segment increased by $50.7 million, or 196.5% in the first nine months of September 30, 2018 compared to the first nine months of September 30, 2017, primarily driven by the following:


•	the addition of approximately 300 convenience stores on July 1, 2017 in connection with the Delek/Alon Merger.

Contribution Margin

Q3 2018 vs. Q3 2017

Contribution margin for the retail segment increased by $1.8 million, a 13.3% improvement in contribution margin percentage, in the third quarter of 2018 compared to the third quarter of 2017, primarily driven by the following:


•	a 24.9% increase in fuel sales revenue primarily attributable to a 21.1% increase in average sales price per gallon quarter over quarter, largely offset by a 22.3% increase in average cost per gallon, the combination of which resulted in a $0.03 per gallon improvement in retail fuel margin per gallon during the quarter, while merchandise margins and operating expenses remained relatively flat.

YTD 2018 vs. YTD 2017

Contribution margin for the retail segment increased by $32.3 million, a 239.3% improvement in contribution margin percentage, in the first nine months of September 30, 2018 compared to the first nine months of September 30, 2017, primarily driven by the following:


•	the addition of approximately 300 convenience stores on July 1, 2017 in connection with the Delek/Alon Merger.

Management's Discussion and Analysis

Management's Discussion and Analysis

Liquidity and Capital Resources

Our primary sources of liquidity are cash generated from our operating activities, borrowings under our debt facilities and potential issuances of additional equity and debt securities. We believe that cash generated from these sources will be sufficient to satisfy the anticipated cash requirements associated with our existing operations and capital expenditures for at least the next 12 months.

Cash Flows

The following table sets forth a summary of our consolidated cash flows (in millions):



	Nine Months Ended September 30,
	2018			2017
Cash Flow Data:
Operating activities	$	201.2		$	72.4
Investing activities	(37.2		)	106.2
Financing activities	3.2			(29.8		)
Net increase (decrease)	$	167.2		$	148.8

We adopted new accounting guidance on January 1, 2018 that resulted in a reclassification of $10.9 million of distributions received in the nine months ended September 30, 2017 from cash flows of operating activities to cash flows of investing activities, as discussed further in Note 1 of the condensed consolidated financial statements in Item 1, Financial Statement.

Cash Flows from Operating Activities

Net cash provided by operating activities was $201.2 million for the nine months ended September 30, 2018, compared to $72.4 million for the comparable period of 2017. The increase in cash flows from operations was partially due to an increase in net income, which for the nine months ended September 30, 2018 was $253.0 million, compared to $97.5 million in the same period of 2017. Additionally, in the nine months ended September 30, 2017, net income included a non-cash gain on remeasurement of equity method investment of $190.1 million for which there was no comparable activity in the current period. This increase was partially offset by increases in cash used to purchase inventory and other current assets, decreases in cash received on accounts receivable and increases in fair value of derivatives. Additionally partially offsetting the increase, net income for the nine months ended September 30, 2018 included a non-cash benefit of deferred income taxes of $34.7 million in 2018 compared to expense of $97.8 million in the prior year.

Cash Flows from Investing Activities

Net cash used in investing activities was $37.2 million for the first nine months of 2018, compared to net cash provided of $106.2 million in the comparable period of 2017. The decrease in cash flows provided by investing activities was primarily due to an increase in cash purchases of property, plant and equipment, which increased from $108.4 million in 2017, to $228.0 million in 2018, and a $9.9 million decrease in distributions received from equity method investments. Additionally, $200.5 million in cash was acquired in 2017 with the Delek/Alon Merger. This decrease was partially offset by proceeds from sales of discontinued operations of $84.9 million and proceeds from the sale of asphalt assets of $110.8 million received in 2018.

Cash Flows from Financing Activities

Net cash provided by financing activities was $3.2 million for the nine months ended September 30, 2018, compared to cash used of $29.8 million in the comparable 2017 period. We completed the Refinancing transaction as well as extinguished the Convertible Notes during the nine months ended September 30, 2018. The increase in net cash flows from financing activities was primarily attributable to proceeds from long-term revolvers of $1,749.1 million and proceeds from term debt of $690.6 million, offset by payments on long-term revolvers of $1,227.8 million, payment on term debt of $824.6 million, deferred financing costs paid of $13.2 million, repayment of product financing agreements of $72.4 million, repurchase of common stock of $207.4 million and increases in dividends paid to $58.8 million compared to $31.3 million in the comparable 2017 period.

Cash Position and Indebtedness

As of September 30, 2018, our total cash and cash equivalents were $1,109.1 million and we had total indebtedness of approximately $1,862.0 million. Total unused credit commitments or borrowing base availability, as applicable, under our revolving credit facilities was approximately $873.3 million and we had letters of credit issued of approximately $143.5 million. We believe we were in compliance with our covenants in all debt facilities as of September 30, 2018. See Note 8 of the condensed consolidated financial statements in Item 1, Financial Statements, for additional information about our separate revolving credit facilities.

Management's Discussion and Analysis

Capital Spending

A key component of our long-term strategy is our capital expenditure program. Our capital expenditures for the nine months ended September 30, 2018 were $210.9 million, of which approximately $136.3 million was spent in our refining segment, $7.4 million in our logistics segment, $6.0 million in our retail segment and $61.2 million at the holding company level. The following table summarizes our actual capital expenditures for the nine months ended September 30, 2018 and planned capital expenditures for the full year 2018 by operating segment and major category (in millions):



	Full Year 2018 Forecast		Nine Months Ended September 30, 2018
Refining:
Sustaining maintenance, including turnaround activities	$	79.6	$	59.5
Regulatory	35.3		22.4
Discretionary projects	77.4		54.4
Refining segment total	192.3		136.3
Logistics:
Regulatory	1.5		0.8
Sustaining maintenance	5.5		3.2
Discretionary projects	4.6		3.4
Logistics segment total	11.6		7.4
Retail:
Regulatory	0.4		0.2
Sustaining maintenance	4.3		2.1
Discretionary projects	7.7		3.7
Retail segment total	12.4		6.0
Other:
Regulatory	0.4		0.3
Sustaining maintenance	1.7		—
Discretionary projects	87.1		60.9
Other total	89.2		61.2
Total capital spending	$	305.5	$	210.9

The amount of our capital expenditure budget is subject to change due to unanticipated increases in the cost, scope and completion time for our capital projects. For example, we may experience increases in the cost of and/or timing to obtain necessary equipment required for our continued compliance with government regulations or to complete improvement projects or scheduled maintenance activities. Additionally, the scope and cost of employee or contractor labor expense related to installation of that equipment could exceed our projections. Our capital expenditure budget may also be revised as management continues to evaluate projects for reliability or profitability. Capital spending excludes transaction costs capitalized in the amount of $0.4 million that relate to the Big Spring Logistic Assets Acquisition.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements through the date of the filing of this Quarterly Report on Form 10-Q.

Management's Discussion and Analysis

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

These disclosures should be read in conjunction with the condensed consolidated financial statements, "Management's Discussion and Analysis of Financial Condition and Results of Operations," and other information presented herein, as well as in the "Quantitative and Qualitative Disclosures About Market Risk" section contained in our Annual Report on Form 10-K.

Price Risk Management Activities

At times, we enter into commodity derivative contracts to manage our price exposure to our inventory positions, future purchases of crude oil and ethanol, future sales of refined products or to fix margins on future production. We also enter into future commitments to purchase or sell RINs at fixed prices and quantities, which are used to manage the costs associated with our RINs Obligations. These future RIN commitments meet the definition of derivative instruments under ASC 815, Derivatives and Hedging ("ASC 815"). In accordance with ASC 815, all of these commodity contracts and future purchase commitments are recorded at fair value, and any change in fair value between periods has historically been recorded in the profit and loss section of our condensed consolidated financial statements. Occasionally, at inception, the Company will elect to designate the commodity derivative contracts as cash flow hedges under ASC 815. Gains or losses on commodity derivative contracts accounted for as cash flow hedges are recognized in other comprehensive income on the condensed consolidated balance sheets and, ultimately, when the forecasted transactions are completed, in net revenues or cost of materials and other in the condensed consolidated statements of income.

The following table sets forth information relating to our open commodity derivative contracts as of September 30, 2018 ($ in millions).



	Total Outstanding				Notional Contract Volume by Year of Maturity
Contract Description	Fair Value			Notional Contract Volume	2018	2019	2020
Contracts not designated as hedging instruments:
Crude oil price swaps - long⁽¹⁾	$	(9.4	)	4,496,000	3,443,000	473,000	580,000
Crude oil price swaps - short⁽¹⁾	5.8			3,866,000	2,813,000	473,000	580,000
Inventory, refined product and crack spread swaps - long⁽¹⁾	167.3			62,768,714	56,982,714	4,815,000	971,000
Inventory, refined product and crack spread swaps - short⁽¹⁾	(184.1		)	63,625,714	55,237,714	7,417,000	971,000
RIN commitment contracts - long⁽²⁾	(16.1		)	32,505,000	32,505,000	—	—
RIN commitment contracts - short⁽²⁾	16.9			26,450,000	26,450,000	—	—
Total	$	(19.6	)	193,711,428	177,431,428	13,178,000	3,102,000
Contracts designated as cash flow hedging instruments:
Crude oil price swaps - long⁽¹⁾	$	—		—	—	—	—
Crude oil price swaps - short⁽¹⁾	—			—	—	—	—
Inventory, refined product and crack spread swaps - long⁽¹⁾	8.7			14,928,000	3,937,000	10,991,000	—
Inventory, refined product and crack spread swaps - short⁽¹⁾	(7.5		)	1,085,000	735,000	350,000	—
Total	$	1.2		16,013,000	4,672,000	11,341,000	—

(1)Volume in barrels

(2)Volume in RINs

Management's Discussion and Analysis

Interest Risk Management Activities

We have market exposure to changes in interest rates relating to our outstanding floating rate borrowings, which totaled approximately $1,529.7 million as of September 30, 2018.

We help manage this risk through interest rate swap agreements that we may periodically enter into in order to modify the interest rate characteristics of our outstanding long-term debt. In accordance with ASC 815, all interest rate hedging instruments are recorded at fair value and any changes in the fair value between periods are recognized in earnings. The fair values of our interest rate swaps have been obtained from dealer quotes. These values represent the estimated amount that we would have received or paid to terminate the agreements taking into account the difference between the contract rate of interest and the then-current rates quoted for agreements of similar terms and maturities. We expect that any interest rate derivatives held would reduce our exposure to short-term interest rate movements. As of December 31, 2017, we had four floating-to-fixed interest rate derivative agreements in place for a notional amount of $68.3 million that were to mature in March 2019 that effectively fixed the variable LIBOR interest component of the term loans within the Alon Retail Credit Agreement. These interest rate swap agreements were terminated in connection with the Refinancing on March 30, 2018 - See Note 8 of the condensed consolidated financial statements in Item 1, Financial Statements, for additional information.

The annualized impact of a hypothetical one percent change in interest rates on our floating rate debt as of September 30, 2018 would be to change interest expense by approximately $15.3 million.

Commodity Derivatives Trading Activities

In the first half of 2018, we entered into active trading positions in a variety of commodity derivatives, which include forward physical contracts, swap contracts, and futures contracts. These contracts are classified as held for trading and are recognized at fair value with changes in fair value recognized in the income statement. Trading activities are undertaken by using a range of contract types in combination to create incremental gains by capitalizing on crude oil supply and pricing seasonality. These contracts had remaining durations of less than one year as of September 30, 2018.

The following table sets forth information relating to commodity derivative contracts held for trading purposes as of September 30, 2018.



Contract Description	Less than 1 year
Over the counter forward sales contracts
Notional contract volume ⁽¹⁾	918,755
Weighted-average market price (per barrel)	$	32.05
Contractual volume at fair value (in millions)	$	29.4
Over the counter forward purchase contracts
Notional contract volume ⁽¹⁾	667,038
Weighted-average market price (per barrel)	$	28.81
Contractual volume at fair value (in millions)	$	19.2


⁽¹⁾	Volume in barrels

Management's Discussion and Analysis

ITEM 4. CONTROLS AND PROCEDURES

Our disclosure controls and procedures are designed to provide reasonable assurance that the information that we are required to disclose in reports we file under the Securities Exchange Act of 1934, as amended ("the Exchange Act"), is accumulated and appropriately communicated to management. There have been no changes in our internal control over financial reporting identified in connection with the evaluation required by paragraph (d) of Exchange Act Rules 13a-15 or 15d-15 that occurred during the third quarter of 2018 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

We carried out an evaluation required by Rule 13a-15(b) of the Exchange Act, under the supervision and with the participation of our management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures at the end of the reporting period. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of the end of the reporting period.

Legal Proceedings, Risk Factors, Unregistered Sales of Equity Securities and Other Information

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

In the ordinary conduct of our business, we are from time to time subject to lawsuits, investigations and claims, including, environmental claims and employee-related matters. Although we cannot predict with certainty the ultimate resolution of lawsuits, investigations and claims asserted against us, including civil penalties or other enforcement actions, we do not believe that any currently pending legal proceeding or proceedings to which we are a party will have a material adverse effect on our business, financial condition or results of operations and there have been no material developments to the proceedings previously reported in our Form 10-K and our Quarterly Report on Form 10-Q for the quarter ended June 30, 2018, filed with the SEC on August 9, 2018 to comply with certain SEC regulations.

ITEM 1A. RISK FACTORS

There have been no material changes in the risk factors previously disclosed in "Item 1A. Risk Factors" of our Annual Report on Form 10-K.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

In December 2016, our Board of Directors authorized a share repurchase program for up to $150.0 million of our common stock. Any share repurchases under the repurchase program may be implemented through open market transactions or in privately negotiated transactions, in accordance with applicable securities laws. The timing, price, and size of repurchases will be made at the discretion of management and will depend on prevailing market prices, general economic and market conditions and other considerations. The repurchase program does not obligate us to acquire any particular amount of stock and does not expire. On February 26, 2018, the Board of Directors approved a new $150.0 million authorization to repurchase our common stock. The following table sets forth information with respect to the purchase of shares of our common stock made during the three months ended September 30, 2018 by or on behalf of us or any “affiliated purchaser,” as defined by Rule 10b-18 of the Exchange Act (inclusive of all purchases that have settled as of September 30, 2018):



Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs ⁽¹⁾
July 1 - July 31, 2018	—	$	—	—	$	159,721,210
August 1 - August 31, 2018	479,029	52.19		479,029	134,721,530
September 1 - September 30, 2018	1,427,279	47.04		1,427,279	$	67,585,943
Total	1,906,308	48.33		1,906,308	N/A

⁽¹⁾1,906,308 shares were repurchased during the three months ended September 30, 2018 pursuant to the repurchase program authorized by the Board of Directors in December 2016 for up to $150.0 million of Delek common stock, which was announced on January 3, 2017, and an additional $150.0 million authorization to repurchase Delek common stock, which was announced on February 26, 2018. On November 6, 2018, the Board of Directors authorized the repurchase of an additional $500.0 million of Delek common stock, which was announced on November 6, 2018.

In addition to purchases presented in the table above, we also received 2,692,771 shares from the exercise of call options on September 17, 2018 that were previously acquired to hedge Alon's 3.00% Convertible Notes due 2018, which shares offset the dilution from the issuance of shares of Delek common stock in connection with the settlement of the Convertible Notes.

ITEM 5. OTHER INFORMATION

On November 9, 2018, Delek entered into an Unwind Agreement with the holders of our outstanding common stock Warrants (as defined in Note 8 of the condensed consolidated financial statements in Item 1, Financial Statements). Pursuant to the terms of the Unwind Agreement, we will settle for cash such Warrants with the holders at various prices per Warrant as provided in the Unwind Agreement. The settlement amount will be based on the volume-weighted average price of Delek common stock over a period of sixteen trading days beginning November 9, 2018 (the “Unwind Period”) and taking into account an adjustment for the exercise price of the Warrants. Following the Unwind Period and the satisfaction of the payment obligation, the Warrants will be canceled and the associated rights and obligations terminated.

We have been advised that the holders of the Warrants or their respective affiliates, in order to unwind their hedge positions with respect to the Warrants, are likely to buy shares of Delek common stock in market or private transactions and unwind various derivative transactions with respect to Delek common stock. These activities could have an effect on the trading price of Delek common stock.

Exhibits

ITEM 6. EXHIBITS



Exhibit No.		Description
31.1	§	Certification of the Company’s Chief Executive Officer pursuant to Rule 13a-14(a)/15(d)-14(a) under the Securities Exchange Act of 1934, as amended.
31.2	§	Certification of the Company’s Chief Financial Officer pursuant to Rule 13a-14(a)/15(d)-14(a) under the Securities Exchange Act of 1934, as amended.
32.1	§§	Certification of the Company’s 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	§§	Certification of the Company’s 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		The following materials from Delek US Holdings, Inc.’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2018, formatted in XBRL (eXtensible Business Reporting Language): (i) Condensed Consolidated Balance Sheets as of September 30, 2018 and December 31, 2017 (Unaudited), (ii) Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2018 and 2017 (Unaudited), (iii) Condensed Consolidated Statements of Comprehensive Income for the three and nine months ended September 30, 2018 and 2017 (Unaudited), (iv) Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2018 and 2017 (Unaudited), and (v) Notes to Condensed Consolidated Financial Statements (Unaudited).



§		Filed herewith
§§		Furnished herewith

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.



Delek US Holdings, Inc.

By:	/s/ Ezra Uzi Yemin
	Ezra Uzi Yemin
	Director (Chairman), President and Chief Executive Officer (Principal Executive Officer)

By:	/s/ Kevin Kremke
	Kevin Kremke
	Executive Vice President and Chief Financial Officer (Principal Financial and Accounting Officer)

Dated: November 9, 2018