UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)

☑

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

For the quarterly period ended

~~June~~September 30, 2023


☐						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.)

310 Seven Springs Way, Suite 500	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 ☑ No ☐

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 ☑ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer

☑

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

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

Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class

Trading Symbol

Name of Each Exchange on Which Registered

Common Stock, par value $0.01

New York Stock Exchange

At ~~August~~November 1, 2023, there were ~~64,817,914~~63,933,521 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 ~~June~~September 30, 2023


2 \|

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)


		June 30, 2023		December 31, 2022			September 30, 2023		December 31, 2022
ASSETS	ASSETS					ASSETS
Current assets:	Current assets:					Current assets:
Cash and cash equivalents	Cash and cash equivalents	$	821.6	$	841.3	Cash and cash equivalents	$	901.7	$	841.3
Accounts receivable, net	Accounts receivable, net	1,003.5		1,234.4		Accounts receivable, net	1,166.9		1,234.4

Inventories, net of inventory valuation reserves	Inventories, net of inventory valuation reserves	1,276.4		1,518.5		Inventories, net of inventory valuation reserves	1,179.2		1,518.5

Other current assets	Other current assets	94.6		122.7		Other current assets	85.6		122.7
Total current assets	Total current assets	3,196.1		3,716.9		Total current assets	3,333.4		3,716.9
Property, plant and equipment:	Property, plant and equipment:					Property, plant and equipment:
Property, plant and equipment	Property, plant and equipment	4,577.2		4,349.0		Property, plant and equipment	4,603.1		4,349.0
Less: accumulated depreciation	Less: accumulated depreciation	(1,708.0)		(1,572.6)		Less: accumulated depreciation	(1,768.3)		(1,572.6)
Property, plant and equipment, net	Property, plant and equipment, net	2,869.2		2,776.4		Property, plant and equipment, net	2,834.8		2,776.4
Operating lease right-of-use assets	Operating lease right-of-use assets	169.5		179.5		Operating lease right-of-use assets	160.3		179.5
Goodwill	Goodwill	744.3		744.3		Goodwill	744.3		744.3
Other intangibles, net	Other intangibles, net	305.1		315.6		Other intangibles, net	300.4		315.6
Equity method investments	Equity method investments	363.7		359.7		Equity method investments	371.2		359.7
Other non-current assets	Other non-current assets	121.6		100.4		Other non-current assets	124.6		100.4
Total assets	Total assets	$	7,769.5	$	8,192.8	Total assets	$	7,869.0	$	8,192.8
LIABILITIES AND STOCKHOLDERS’ EQUITY	LIABILITIES AND STOCKHOLDERS’ EQUITY					LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:	Current liabilities:					Current liabilities:
Accounts payable	Accounts payable	$	1,990.1	$	1,745.6	Accounts payable	$	2,006.8	$	1,745.6

Current portion of long-term debt	Current portion of long-term debt	49.5		74.5		Current portion of long-term debt	29.5		74.5
Current portion of obligation under Inventory Intermediation Agreement	Current portion of obligation under Inventory Intermediation Agreement	—		49.9		Current portion of obligation under Inventory Intermediation Agreement	—		49.9
Current portion of operating lease liabilities	Current portion of operating lease liabilities	50.2		49.6		Current portion of operating lease liabilities	49.9		49.6
Accrued expenses and other current liabilities	Accrued expenses and other current liabilities	824.8		1,166.8		Accrued expenses and other current liabilities	916.5		1,166.8
Total current liabilities	Total current liabilities	2,914.6		3,086.4		Total current liabilities	3,002.7		3,086.4
Non-current liabilities:	Non-current liabilities:					Non-current liabilities:
Long-term debt, net of current portion	Long-term debt, net of current portion	2,761.4		2,979.2		Long-term debt, net of current portion	2,608.5		2,979.2
Obligation under Inventory Intermediation Agreement	Obligation under Inventory Intermediation Agreement	453.4		491.8		Obligation under Inventory Intermediation Agreement	502.2		491.8
Environmental liabilities, net of current portion	Environmental liabilities, net of current portion	111.6		111.5		Environmental liabilities, net of current portion	111.6		111.5
Asset retirement obligations	Asset retirement obligations	42.5		41.8		Asset retirement obligations	42.9		41.8
Deferred tax liabilities	Deferred tax liabilities	280.7		266.5		Deferred tax liabilities	304.2		266.5
Operating lease liabilities, net of current portion	Operating lease liabilities, net of current portion	113.4		122.4		Operating lease liabilities, net of current portion	106.8		122.4
Other non-current liabilities	Other non-current liabilities	29.0		23.7		Other non-current liabilities	33.1		23.7
Total non-current liabilities	Total non-current liabilities	3,792.0		4,036.9		Total non-current liabilities	3,709.3		4,036.9
Stockholders’ equity:	Stockholders’ equity:					Stockholders’ equity:
Preferred stock, $0.01 par value, 10,000,000 shares authorized, no shares issued and outstanding	Preferred stock, $0.01 par value, 10,000,000 shares authorized, no shares issued and outstanding	—		—		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, 83,150,295 shares and 84,509,517 shares issued at June 30, 2023 and December 31, 2022, respectively		0.8		0.9
Common stock, $0.01 par value, 110,000,000 shares authorized, 82,241,519 shares and 84,509,517 shares issued at September 30, 2023 and December 31, 2022, respectively						Common stock, $0.01 par value, 110,000,000 shares authorized, 82,241,519 shares and 84,509,517 shares issued at September 30, 2023 and December 31, 2022, respectively	0.8		0.9
Additional paid-in capital	Additional paid-in capital	1,121.8		1,134.1		Additional paid-in capital	1,116.4		1,134.1
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(5.3)		(5.2)		Accumulated other comprehensive loss	(5.3)		(5.2)
Treasury stock, 17,575,527 shares, at cost, at June 30, 2023 and December 31, 2022, respectively		(694.1)		(694.1)
Treasury stock, 17,575,527 shares, at cost, at September 30, 2023 and December 31, 2022, respectively						Treasury stock, 17,575,527 shares, at cost, at September 30, 2023 and December 31, 2022, respectively	(694.1)		(694.1)
Retained earnings	Retained earnings	518.1		507.9		Retained earnings	619.9		507.9
Non-controlling interests in subsidiaries	Non-controlling interests in subsidiaries	121.6		125.9		Non-controlling interests in subsidiaries	119.3		125.9
Total stockholders’ equity	Total stockholders’ equity	1,062.9		1,069.5		Total stockholders’ equity	1,157.0		1,069.5
Total liabilities and stockholders’ equity	Total liabilities and stockholders’ equity	$	7,769.5	$	8,192.8	Total liabilities and stockholders’ equity	$	7,869.0	$	8,192.8

See accompanying notes to the condensed consolidated financial statements


3 \|

Financial Statements

Delek US Holdings, Inc.

Condensed Consolidated Statements of Income (unaudited)

(In millions, except share and per share data)


		Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,

		2023		2022		2023		2022				2023		2022		2023		2022
Net revenues	Net revenues	$	4,195.6	$	5,982.6	$	8,119.9	$	10,441.7		Net revenues	$	4,748.4	$	5,324.9	$	12,868.3	$	15,766.6
Cost of sales:	Cost of sales:										Cost of sales:
Cost of materials and other	Cost of materials and other	3,766.6		5,082.6		7,206.2		9,235.1			Cost of materials and other	4,122.1		4,916.0		11,328.3		14,151.1
Operating expenses (excluding depreciation and amortization presented below)	Operating expenses (excluding depreciation and amortization presented below)	188.7		192.7		359.5		335.1			Operating expenses (excluding depreciation and amortization presented below)	217.7		201.3		577.2		536.4
Depreciation and amortization	Depreciation and amortization	82.6		62.8		159.4		125.5			Depreciation and amortization	83.7		66.5		243.1		192.0
Total cost of sales	Total cost of sales	4,037.9		5,338.1		7,725.1		9,695.7			Total cost of sales	4,423.5		5,183.8		12,148.6		14,879.5

Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below)	Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below)	31.1		34.0		58.1		61.4			Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below)	22.7		28.2		80.8		89.6
General and administrative expenses	General and administrative expenses	75.8		122.3		147.3		172.5			General and administrative expenses	72.0		59.3		219.3		231.8
Depreciation and amortization	Depreciation and amortization	6.8		5.2		13.4		10.8			Depreciation and amortization	7.6		6.4		21.0		17.2

Other operating income, net	Other operating income, net	(6.1)		(10.3)		(16.9)		(38.7)			Other operating income, net	(2.1)		(5.8)		(19.0)		(44.5)
Total operating costs and expenses	Total operating costs and expenses	4,145.5		5,489.3		7,927.0		9,901.7			Total operating costs and expenses	4,523.7		5,271.9		12,450.7		15,173.6
Operating income	Operating income	50.1		493.3		192.9		540.0			Operating income	224.7		53.0		417.6		593.0
Interest expense, net	Interest expense, net	80.4		43.6		156.9		82.0			Interest expense, net	82.3		50.7		239.2		132.7
Income from equity method investments	Income from equity method investments	(25.5)		(15.7)		(40.1)		(26.6)			Income from equity method investments	(27.0)		(17.8)		(67.1)		(44.4)

Other expense (income), net	Other expense (income), net	0.5		(3.6)		(6.6)		(2.3)			Other expense (income), net	1.8		(0.7)		(4.8)		(3.0)
Total non-operating expense, net	Total non-operating expense, net	55.4		24.3		110.2		53.1			Total non-operating expense, net	57.1		32.2		167.3		85.3
(Loss) income before income tax (benefit) expense		(5.3)		469.0		82.7		486.9
Income tax (benefit) expense		(3.8)		100.4		12.0		103.5
Income before income tax expense											Income before income tax expense	167.6		20.8		250.3		507.7
Income tax expense											Income tax expense	31.5		4.0		43.5		107.5

Net (loss) income		(1.5)		368.6		70.7		383.4
Net income											Net income	136.1		16.8		206.8		400.2
Net income attributed to non-controlling interests	Net income attributed to non-controlling interests	6.8		6.8		14.7		15.0			Net income attributed to non-controlling interests	7.4		9.4		22.1		24.4
Net (loss) income attributable to Delek		$	(8.3)	$	361.8	$	56.0	$	368.4
Net income attributable to Delek											Net income attributable to Delek	$	128.7	$	7.4	$	184.7	$	375.8

Basic (loss) income per share		$	(0.13)	$	5.11	$	0.84	$	5.12
Basic income per share											Basic income per share	$	1.98	$	0.11	$	2.80	$	5.26

Diluted (loss) income per share		$	(0.13)	$	5.05	$	0.84	$	5.07
Diluted income per share											Diluted income per share	$	1.97	$	0.10	$	2.78	$	5.21
Weighted average common shares outstanding:	Weighted average common shares outstanding:										Weighted average common shares outstanding:
Basic	Basic	65,773,609		70,805,458		66,359,537		72,014,151			Basic	64,889,504		70,471,645		65,864,141		71,494,332
Diluted	Diluted	65,773,609		71,679,954		66,835,322		72,675,313			Diluted	65,464,970		71,109,364		66,372,335		72,148,638

See accompanying notes to the condensed consolidated financial statements


4 \|

Financial Statements

Delek US Holdings, Inc.

Condensed Consolidated Statements of Comprehensive Income (unaudited)

(In millions)


		Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,

		2023		2022		2023		2022				2023		2022		2023		2022
Net (loss) income		$	(1.5)	$	368.6	$	70.7	$	383.4
Net income											Net income	$	136.1	$	16.8	$	206.8	$	400.2
Other comprehensive loss:	Other comprehensive loss:										Other comprehensive loss:

Other loss, net of taxes	Other loss, net of taxes	(0.1)		(0.1)		(0.1)		(0.2)			Other loss, net of taxes	—		(0.1)		(0.1)		(0.2)
Total other comprehensive loss	Total other comprehensive loss	(0.1)		(0.1)		(0.1)		(0.2)			Total other comprehensive loss	—		(0.1)		(0.1)		(0.2)
Comprehensive (loss) income		$	(1.6)	$	368.5	$	70.6	$	383.2
Comprehensive income											Comprehensive income	$	136.1	$	16.7	$	206.7	$	400.0
Comprehensive income attributable to non-controlling interest	Comprehensive income attributable to non-controlling interest	6.8		6.8		14.7		15.0			Comprehensive income attributable to non-controlling interest	7.4		9.4		22.1		24.4
Comprehensive (loss) income attributable to Delek		$	(8.4)	$	361.7	$	55.9	$	368.2
Comprehensive income attributable to Delek											Comprehensive income attributable to Delek	$	128.7	$	7.3	$	184.6	$	375.6

See accompanying notes to the condensed consolidated financial statements


5 \|

Financial Statements

Delek US Holdings, Inc.

Condensed Consolidated Statements of Changes in Stockholders' Equity (unaudited)

(In millions, except share and per share data)


		Three Months Ended June 30, 2023																	Three Months Ended September 30, 2023
		Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Treasury Stock			Non-Controlling Interest in Subsidiaries		Total Stockholders' Equity			Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Treasury Stock			Non-Controlling Interest in Subsidiaries		Total Stockholders' Equity
		Shares	Amount								Shares	Amount							Shares	Amount								Shares	Amount
Balance at March 31, 2023		84,569,103	$	0.9	$	1,141.2	$	(5.2)	$	557.2	(17,575,527)	$	(694.1)	$	124.3	$	1,124.3
Balance at June 30, 2023																		Balance at June 30, 2023	83,150,295	$	0.8	$	1,121.8	$	(5.3)	$	518.1	(17,575,527)	$	(694.1)	$	121.6	$	1,062.9

Net (loss) income		—	—		—		—		(8.3)		—	—		6.8		(1.5)
Net income																		Net income	—	—		—		—		128.7		—	—		7.4		136.1

Common stock dividends ($0.23 per share)		—	—		—		—		(15.0)		—	—		—		(15.0)
Common stock dividends ($0.235 per share)																		Common stock dividends ($0.235 per share)	—	—		—		—		(15.2)		—	—		—		(15.2)
Distributions to non-controlling interests	Distributions to non-controlling interests	—	—		—		—		—		—	—		(9.6)		(9.6)		Distributions to non-controlling interests	—	—		—		—		—		—	—		(9.7)		(9.7)
Equity-based compensation expense	Equity-based compensation expense	—	—		5.7		—		—		—	—		0.2		5.9		Equity-based compensation expense	—	—		8.0		—		—		—	—		0.2		8.2

Repurchase of common stock	Repurchase of common stock	(1,795,335)	(0.1)		(24.2)		—		(15.7)		—	—		—		(40.0)		Repurchase of common stock	(981,690)	—		(13.3)		—		(11.7)		—	—		—		(25.0)

Taxes paid due to the net settlement of equity-based compensation	Taxes paid due to the net settlement of equity-based compensation	—	—		(2.9)		—		—		—	—		(0.1)		(3.0)		Taxes paid due to the net settlement of equity-based compensation	—	—		(0.7)		—		—		—	—		(0.3)		(1.0)
Exercise of equity-based awards	Exercise of equity-based awards	308,196	—		—		—		—		—	—		—		—		Exercise of equity-based awards	48,154	—		—		—		—		—	—		—		—
Other	Other	68,331	—		2.0		(0.1)		(0.1)		—	—		—		1.8		Other	24,760	—		0.6		—		—		—	—		0.1		0.7
Balance at June 30, 2023		83,150,295	$	0.8	$	1,121.8	$	(5.3)	$	518.1	(17,575,527)	$	(694.1)	$	121.6	$	1,062.9
Balance at September 30, 2023																		Balance at September 30, 2023	82,241,519	$	0.8	$	1,116.4	$	(5.3)	$	619.9	(17,575,527)	$	(694.1)	$	119.3	$	1,157.0

Three Months Ended June 30, 2022
Common Stock Additional Paid-in Capital Accumulated Other Comprehensive Loss Retained Earnings Treasury Stock Non-Controlling Interest in Subsidiaries Total Stockholders' Equity
Shares Amount Shares Amount
Balance at March 31, 2022 88,320,612 $ 0.9 $ 1,156.0 $ (3.9) $ 391.3 (17,575,527) $ (694.1) $ 124.5 $ 974.7
Net income — — — — 361.8 — — 6.8 368.6
Distributions to non-controlling interests — — — — — — — (9.0) (9.0)
Equity-based compensation expense — — 7.1 — — — — 0.1 7.2
Taxes paid due to the net settlement of equity-based compensation — — (4.0) — — — — — (4.0)
Exercise of equity-based awards 289,971 — — — — — — — —
Other — — — — (0.1) — — — (0.1)
Balance at June 30, 2022 88,610,583 $ 0.9 $ 1,159.1 $ (3.9) $ 753.0 (17,575,527) $ (694.1) $ 122.4 $ 1,337.4


	Three Months Ended September 30, 2022
	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Treasury Stock			Non-Controlling Interest in Subsidiaries		Total Stockholders' Equity
	Shares	Amount								Shares	Amount
Balance at June 30, 2022	88,610,583	$	0.9	$	1,159.1	$	(3.9)	$	753.0	(17,575,527)	$	(694.1)	$	122.4	$	1,337.4


Net income	—	—		—		—		7.4		—	—		9.4		16.8


Common stock dividends ($0.40 per share)	—	—		—		—		(28.3)		—	—		—		(28.3)
Distributions to non-controlling interests	—	—		—		—		—		—	—		(9.2)		(9.2)
Equity-based compensation expense	—	—		7.7		—		—		—	—		0.1		7.8


Repurchase of common stock	(1,435,602)	—		(40.0)		—		—		—	—		—		(40.0)

Taxes paid due to the net settlement of equity-based compensation	—	—		(1.1)		—		—		—	—		—		(1.1)
Exercise of equity-based awards	53,522	—		—		—		—		—	—		—		—
Other	—	—		—		(0.1)		(0.3)		—	—		—		(0.4)
Balance at September 30, 2022	87,228,503	$	0.9	$	1,125.7	$	(4.0)	$	731.8	(17,575,527)	$	(694.1)	$	122.7	$	1,283.0


6 \|

Financial Statements

Delek US Holdings, Inc.

Condensed Consolidated Statements of Changes in Stockholders' Equity (unaudited)

(In millions, except share and per share data)


		Six Months Ended June 30, 2023																									Nine Months Ended September 30, 2023
		Common Stock			Additional Paid-in Capital				Accumulated Other Comprehensive Loss			Retained Earnings		Treasury Shares				Non-Controlling Interest in Subsidiaries				Total Stockholders' Equity					Common Stock						Additional Paid-in Capital				Accumulated Other Comprehensive Loss				Retained Earnings				Treasury Shares						Non-Controlling Interest in Subsidiaries				Total Stockholders' Equity
		Shares	Amount								Shares			Amount							Shares					Amount										Shares								Amount
Balance at December 31, 2022	Balance at December 31, 2022	84,509,517	$	0.9			$	1,134.1				$	(5.2)	$	507.9	(17,575,527)				$	(694.1)			$	125.9		$	1,069.5	Balance at December 31, 2022			84,509,517			$	0.9			$	1,134.1			$	(5.2)		$	507.9			(17,575,527)			$	(694.1)			$	125.9	$	1,069.5

Net income	Net income	—	—		—				—			56.0		—		—		14.7				70.7			Net income		—			—			—				—				184.7				—			—			22.1				206.8

Common stock dividends ($0.45 per share)		—	—		—				—			(29.7)		—		—		—				(29.7)
Common stock dividends ($0.685 per share)																									Common stock dividends ($0.685 per share)		—			—			—				—				(44.9)				—			—			—				(44.9)
Distributions to non-controlling interests	Distributions to non-controlling interests	—	—		—				—			—		—		—		(19.1)				(19.1)			Distributions to non-controlling interests		—			—			—				—				—				—			—			(28.8)				(28.8)
Equity-based compensation expense	Equity-based compensation expense	—	—		12.0				—			—		—		—		0.3				12.3			Equity-based compensation expense		—			—			20.0				—				—				—			—			0.5				20.5

Repurchase of common stock	Repurchase of common stock	(1,811,627)	(0.1)		(24.4)				—			(15.9)		—		—		—				(40.4)			Repurchase of common stock		(2,793,317)			(0.1)			(37.7)				—				(27.6)				—			—			—				(65.4)

Taxes paid due to the net settlement of equity-based compensation	Taxes paid due to the net settlement of equity-based compensation	—	—		(3.4)				—			—		—		—		(0.2)				(3.6)			Taxes paid due to the net settlement of equity-based compensation		—			—			(4.1)				—				—				—			—			(0.5)				(4.6)
Exercise of equity-based awards	Exercise of equity-based awards	361,839	—		—				—			—		—		—		—				—			Exercise of equity-based awards		409,993			—			—				—				—				—			—			—				—

Other	Other	90,566	—		3.5				(0.1)			(0.2)		—		—		—				3.2			Other		115,326			—			4.1				(0.1)				(0.2)				—			—			0.1				3.9
Balance at June 30, 2023		83,150,295	$	0.8	$	1,121.8			$	(5.3)		$	518.1	(17,575,527)		$	(694.1)	$	121.6			$	1,062.9
Balance at September 30, 2023																									Balance at September 30, 2023		82,241,519			$	0.8		$	1,116.4			$	(5.3)			$	619.9			(17,575,527)			$	(694.1)		$	119.3			$	1,157.0

Six Months Ended June 30, 2022
Common Stock Additional Paid-in Capital Accumulated Other Comprehensive Loss Retained Earnings Treasury Stock Non-Controlling Interest in Subsidiaries Total Stockholders' Equity
Shares Amount Shares Amount
Balance at December 31, 2021 91,772,080 $ 0.9 $ 1,206.5 $ (3.8) $ 384.7 (17,575,527) $ (694.1) $ 119.8 $ 1,014.0
Net income — — — — 368.4 — — 15.0 383.4
Equity-based compensation expense — — 12.4 — — — — 0.2 12.6
Distribution to non-controlling interest — — — — — — — (17.7) (17.7)
Sale of Delek Logistics common limited partner units, net — — 8.5 — — — — 5.1 13.6
Purchase of Delek common stock from IEP Energy Holding LLC (3,497,268) — (64.0) — — — — — (64.0)
Taxes paid due to the net settlement of equity-based compensation — — (4.3) — — — — — (4.3)
Exercise of equity-based awards 335,771 — — — — — — — —
Other — — — (0.1) (0.1) — — — (0.2)
Balance at June 30, 2022 88,610,583 $ 0.9 $ 1,159.1 $ (3.9) $ 753.0 (17,575,527) $ (694.1) $ 122.4 $ 1,337.4


	Nine Months Ended September 30, 2022
	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Loss		Retained Earnings		Treasury Stock			Non-Controlling Interest in Subsidiaries		Total Stockholders' Equity
	Shares	Amount								Shares	Amount
Balance at December 31, 2021	91,772,080	$	0.9	$	1,206.5	$	(3.8)	$	384.7	(17,575,527)	$	(694.1)	$	119.8	$	1,014.0
Net income	—	—		—		—		375.8		—	—		24.4		400.2
Common stock dividends ($0.40 per share)	—	—		—		—		(28.3)		—	—		—		(28.3)
Equity-based compensation expense	—	—		20.1		—		—		—	—		0.3		20.4
Distributions to non-controlling interests	—	—		—		—		—		—	—		(26.9)		(26.9)
Sale of Delek Logistics common limited partner units, net	—	—		8.5		—		—		—	—		5.1		13.6
Repurchase of common stock	(1,435,602)	—		(40.0)		—		—		—	—		—		(40.0)
Purchase of Delek common stock from IEP Energy Holding LLC	(3,497,268)	—		(64.0)		—		—		—	—		—		(64.0)
Taxes paid due to the net settlement of equity-based compensation	—	—		(5.4)		—		—		—	—		—		(5.4)
Exercise of equity-based awards	389,293	—		—		—		—		—	—		—		—
Other	—	—		—		(0.2)		(0.4)		—	—		—		(0.6)
Balance at September 30, 2022	87,228,503	$	0.9	$	1,125.7	$	(4.0)	$	731.8	(17,575,527)	$	(694.1)	$	122.7	$	1,283.0

See accompanying notes to the condensed consolidated financial statements


7 \|

Financial Statements

Delek US Holdings, Inc.

Condensed Consolidated Statements of Cash Flows (unaudited)

(In millions)


		Six Months Ended June 30,				Nine Months Ended September 30,

		2023		2022				2023		2022
Cash flows from operating activities:	Cash flows from operating activities:						Cash flows from operating activities:
Net income	Net income	$	70.7	$	383.4		Net income	$	206.8	$	400.2
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:						Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	172.8		136.3			Depreciation and amortization	264.1		209.2

Non-cash lease expense	Non-cash lease expense	30.2		35.4			Non-cash lease expense	44.2		48.5
Deferred income taxes	Deferred income taxes	12.0		93.9			Deferred income taxes	24.9		95.6

Income from equity method investments	Income from equity method investments	(40.1)		(26.6)			Income from equity method investments	(67.1)		(44.4)
Dividends from equity method investments	Dividends from equity method investments	19.5		14.5			Dividends from equity method investments	35.8		26.3
Non-cash lower of cost or market/net realizable value adjustment	Non-cash lower of cost or market/net realizable value adjustment	(9.6)		(1.2)			Non-cash lower of cost or market/net realizable value adjustment	(6.2)		19.1

Equity-based compensation expense	Equity-based compensation expense	12.3		12.6			Equity-based compensation expense	20.5		20.4
Other	Other	6.3		7.8			Other	6.5		10.4
Changes in assets and liabilities:	Changes in assets and liabilities:						Changes in assets and liabilities:
Accounts receivable	Accounts receivable	240.2		(513.9)			Accounts receivable	78.6		(230.0)
Inventories and other current assets	Inventories and other current assets	280.6		(533.9)			Inventories and other current assets	371.5		(419.8)
Fair value of derivatives	Fair value of derivatives	(19.4)		(74.9)			Fair value of derivatives	(8.6)		(56.2)
Accounts payable and other current liabilities	Accounts payable and other current liabilities	(134.9)		777.4			Accounts payable and other current liabilities	54.6		524.8
Obligation under Inventory Intermediation Agreements	Obligation under Inventory Intermediation Agreements	(146.3)		283.0			Obligation under Inventory Intermediation Agreements	(97.5)		108.7
Non-current assets and liabilities, net	Non-current assets and liabilities, net	(4.1)		(7.9)			Non-current assets and liabilities, net	(5.3)		3.3

Net cash provided by operating activities	Net cash provided by operating activities	490.2		585.9			Net cash provided by operating activities	922.8		716.1
Cash flows from investing activities:	Cash flows from investing activities:						Cash flows from investing activities:
Acquisition of 3 Bear	Acquisition of 3 Bear	—		(621.7)			Acquisition of 3 Bear	—		(625.4)
Equity method investment contributions	Equity method investment contributions	—		(0.1)			Equity method investment contributions	—		(0.1)
Distributions from equity method investments	Distributions from equity method investments	7.3		1.7			Distributions from equity method investments	10.5		1.7
Purchases of property, plant and equipment	Purchases of property, plant and equipment	(277.6)		(98.1)			Purchases of property, plant and equipment	(338.3)		(192.8)
Purchase of equity securities	Purchase of equity securities	(9.0)		—			Purchase of equity securities	(11.0)		—
Purchases of intangible assets	Purchases of intangible assets	(1.3)		(3.8)			Purchases of intangible assets	(2.6)		(4.5)
Proceeds from sale of property, plant and equipment	Proceeds from sale of property, plant and equipment	0.7		1.1			Proceeds from sale of property, plant and equipment	1.3		1.2

Insurance proceeds							Insurance proceeds	1.5		—

Net cash used in investing activities	Net cash used in investing activities	(279.9)		(720.9)			Net cash used in investing activities	(338.6)		(819.9)
Cash flows from financing activities:	Cash flows from financing activities:						Cash flows from financing activities:
Proceeds from long-term revolvers	Proceeds from long-term revolvers	1,547.0		1,470.9			Proceeds from long-term revolvers	2,615.4		1,571.4
Payments on long-term revolvers	Payments on long-term revolvers	(1,781.5)		(848.0)			Payments on long-term revolvers	(3,019.4)		(1,022.5)

Payments on term debt	Payments on term debt	(12.3)		(26.7)			Payments on term debt	(18.4)		(38.9)

Proceeds from product financing agreements	Proceeds from product financing agreements	656.0		508.2			Proceeds from product financing agreements	908.2		744.6
Repayments of product financing agreements	Repayments of product financing agreements	(603.2)		(511.0)			Repayments of product financing agreements	(922.6)		(704.6)
Proceeds from Inventory Intermediation Agreement	Proceeds from Inventory Intermediation Agreement	32.2		—			Proceeds from Inventory Intermediation Agreement	32.2		—
Proceeds from termination of Supply & Offtake Obligation	Proceeds from termination of Supply & Offtake Obligation	25.8		—			Proceeds from termination of Supply & Offtake Obligation	25.8		—
Taxes paid due to the net settlement of equity-based compensation	Taxes paid due to the net settlement of equity-based compensation	(3.6)		(4.3)			Taxes paid due to the net settlement of equity-based compensation	(4.6)		(5.4)

Repurchase of common stock	Repurchase of common stock	(40.4)		—			Repurchase of common stock	(65.4)		(40.0)

Distribution to non-controlling interest	Distribution to non-controlling interest	(19.1)		(17.7)			Distribution to non-controlling interest	(28.8)		(26.9)
Proceeds from sale of Delek Logistics common limited partner units	Proceeds from sale of Delek Logistics common limited partner units	—		16.4			Proceeds from sale of Delek Logistics common limited partner units	—		16.4

Purchase of Delek common stock from IEP Energy Holding LLC	Purchase of Delek common stock from IEP Energy Holding LLC	—		(64.0)			Purchase of Delek common stock from IEP Energy Holding LLC	—		(64.0)
Dividends paid	Dividends paid	(29.7)		—			Dividends paid	(44.9)		(28.3)

Deferred financing costs paid	Deferred financing costs paid	(1.2)		(0.7)			Deferred financing costs paid	(1.3)		(0.7)

Net cash (used in) provided by financing activities	Net cash (used in) provided by financing activities	(230.0)		523.1			Net cash (used in) provided by financing activities	(523.8)		401.1
Net (decrease) increase in cash and cash equivalents		(19.7)		388.1
Net increase in cash and cash equivalents							Net increase in cash and cash equivalents	60.4		297.3
Cash and cash equivalents at the beginning of the period	Cash and cash equivalents at the beginning of the period	841.3		856.5			Cash and cash equivalents at the beginning of the period	841.3		856.5

Cash and cash equivalents at the end of the period	Cash and cash equivalents at the end of the period	$	821.6	$	1,244.6		Cash and cash equivalents at the end of the period	$	901.7	$	1,153.8

Delek US Holdings, Inc.

Condensed Consolidated Statements of Cash Flows (unaudited) (Continued)

(In millions)


		Six Months Ended June 30,				Nine Months Ended September 30,
		2023		2022				2023		2022

Supplemental disclosures of cash flow information:	Supplemental disclosures of cash flow information:						Supplemental disclosures of cash flow information:
Cash paid during the period for:	Cash paid during the period for:						Cash paid during the period for:
Interest, net of capitalized interest of $1.0 million and $0.7 million in the 2023,and 2022 periods, respectively		$	159.9	75.4
Interest, net of capitalized interest of $3.2 million and $1.5 million in the 2023,and 2022 periods, respectively							Interest, net of capitalized interest of $3.2 million and $1.5 million in the 2023,and 2022 periods, respectively	$	232.3	113.5
Income taxes	Income taxes	$	6.6	$	9.2		Income taxes	$	8.3	$	26.5
Non-cash investing activities:	Non-cash investing activities:						Non-cash investing activities:

Decrease in accrued capital expenditures	Decrease in accrued capital expenditures	$	(24.3)	$	(4.8)		Decrease in accrued capital expenditures	$	(36.7)	$	(10.5)
Non-cash financing activities:	Non-cash financing activities:						Non-cash financing activities:

Non-cash lease liability arising from obtaining right-of-use assets during the period	Non-cash lease liability arising from obtaining right-of-use assets during the period	$	22.9	$	11.3		Non-cash lease liability arising from obtaining right-of-use assets during the period	$	28.2	$	17.5

See accompanying notes to the condensed consolidated financial statements


8 \|

Notes to Condensed Financial Statements (Unaudited)

Delek US Holdings, Inc.

Notes to Condensed Consolidated Financial Statements (unaudited)

1. Organization and Basis of Presentation

Delek US Holdings, Inc. operates through its consolidated subsidiaries, which include Delek US Energy, Inc. ("Delek Energy") (and its subsidiaries) and Alon USA Energy, Inc. ("Alon") (and its subsidiaries). The terms "we," "our," "us," "Delek" and the "Company" are used in this report to refer to Delek and its consolidated subsidiaries. Delek's common stock is listed on the New York Stock Exchange ("NYSE") under the symbol "DK."

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 United States ("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 consolidated financial statements included in our Annual Report on Form 10-K filed with the Securities and Exchange Commission ("SEC") on March 1, 2023 (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, 2022 included in our Annual Report on Form 10-K.

Our condensed consolidated financial statements include Delek Logistics Partners, LP ("Delek Logistics", NYSE:DKL), which is a variable interest entity ("VIE"). On June 1, 2022, DKL Delaware Gathering, LLC, a subsidiary of the Delek Logistics, acquired 100% of the limited liability company interests in 3 Bear Delaware Holding – NM, LLC ("3 Bear") from 3 Bear Energy – New Mexico LLC (subsequently renamed to Delek Delaware Gathering ("Delaware Gathering")), related to their crude oil and natural gas gathering, processing and transportation businesses, as well as water disposal and recycling operations, located in the Delaware Basin of New Mexico (the "Delaware Gathering Acquisition"). See Note 2 - Acquisitions for additional information. 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. 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.

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.

Reclassifications

Certain prior period amounts have been reclassified in order to conform to the current period presentation.

New Accounting Pronouncements Adopted During 2023

ASU 2023 -03 , Presentation of Financial Statements (Topic 205), Income Statement - Reporting Comprehensive Income (Topic 220), Distinguishing Liabilities from Equity (Topic 480), Equity (Topic 505), and Compensation - Stock Compensation (Topic 718)

In July 2023, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2023-03, Presentation of Financial Statements (Topic 205), Income Statement-Reporting Comprehensive Income (Topic 220), Distinguishing Liabilities from Equity (Topic 480), Equity (Topic 505), and Compensation-Stock Compensation (Topic 718) (“ASU 2023-03”). This ASU amends or supersedes various SEC paragraphs within the FASB Accounting Standards Codification to conform to past SEC announcements and guidance issued by the SEC. ASU 2023-03 does not provide any new guidance, so there is no transition or effective date. We adopted ASU 2023-03 in July 2023. There was no material impact on our condensed consolidated financial statements.

Accounting Pronouncements Not Yet Adopted

ASU 2023-06, Codification Amendments in Response to the SEC's Disclosure Update and Simplification Initiative

In October 2023, the FASB issued ASU 2023-06 Codification Amendments in Response to the SEC's Disclosure Update and Simplification Initiative ("ASU 2023-06"). The main provision of ASU 2023-06 is to clarify or improve disclosure and presentation requirements of a variety of topics, which will allow users to more easily compare entities subject to the SEC's existing disclosures with those entities that were not previously subject to the requirements, and align the requirements in the FASB accounting standard codification with the SEC's regulations. The effective date for each amendment will be the date on which the SEC’s removal of that related disclosure from Regulation S-X or Regulation S-K becomes effective, with early adoption prohibited. The Company is currently evaluating the provisions of the amendments and the impact on its future consolidated statements, but does not currently expect adopting this new guidance will have a material impact on its consolidated financial statements and related disclosures.


9 \|

Notes to Condensed Financial Statements (Unaudited)

2. Acquisitions

Delek Delaware Gathering (formally 3 Bear)

Delek Logistics completed the Delaware Gathering Acquisition on June 1, 2022 (the "Acquisition Date"), in which it acquired crude oil and natural gas gathering, processing and transportation and storage operations, as well as water disposal and recycling operations, located in the Delaware Basin of New Mexico.

The purchase price for Delaware Gathering was $628.3 million. The Delaware Gathering Acquisition was financed through a combination of cash on hand and borrowings under the Delek Logistics' Revolving Facility (as discussed in Note 9 of these consolidated financial statements).

For the three and ~~six~~nine months ended ~~June~~September 30, 2023, we incurred no incremental direct acquisition and integration costs. For the three and ~~six~~nine months ended ~~June~~September 30, 2022, we incurred ~~$6.2~~$4.2 million and ~~$6.4~~$10.6 million, respectively, in incremental direct acquisition and integration costs that principally consist of legal, advisory and other professional fees. Such costs are included in general and administrative expenses in the accompanying condensed consolidated statements of income for these periods.

The Delaware Gathering Acquisition was accounted for using the acquisition method of accounting, whereby the purchase price was allocated to the tangible and intangible assets acquired and the liabilities assumed based on their fair values. The excess of the consideration paid over the fair value of the net assets acquired was recorded as goodwill.


~~9 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

Determination of Purchase Price

The table below represents the purchase price (in millions):


Base purchase price:	$	624.7
Add: closing net working capital (as defined in the 3 Bear Purchase Agreement)	3.6
Less: closing indebtedness (as defined in the 3 Bear Purchase Agreement)	(80.6)
Cash paid for the adjusted purchase price	547.7
Cash paid to payoff 3 Bear credit agreement (as defined in the 3 Bear Purchase Agreement)	80.6
Purchase price	$	628.3

Purchase Price Allocation

The following table summarizes the final fair values of assets acquired and liabilities assumed in the Delaware Gathering Acquisition as of June 1, 2022 (in millions):


Assets acquired:
Cash and cash equivalents	$	2.7
Accounts receivables, net	28.9
Inventories	1.8
Other current assets	1.0
Property, plant and equipment	382.8
Operating lease right-of-use assets	7.4
Goodwill	14.8
Other intangibles, net (1)	223.5
Other non-current assets	0.5
Total assets acquired	663.4

Liabilities assumed:
Accounts payable	8.0
Accrued expenses and other current liabilities	22.4
Current portion of operating lease liabilities	1.0
Asset retirement obligations	2.3
Operating lease liabilities, net of current portion	1.4
Total liabilities assumed	35.1
Fair value of net assets acquired	$	628.3

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

•Customer relationships intangible that is subject to amortization with a preliminary fair value of $210.0 million, which will be amortized over an 11.6-year useful life.

•Rights-of-way intangible that is subject to amortization with a preliminary fair value of $13.5 million, which will be amortized over the weighted-average useful life of 25.4 years.


10 \|

Notes to Condensed Financial Statements (Unaudited)

The fair value of property, plant and equipment was based on the combination of the cost and market approaches. Key assumptions in the cost approach include determining the replacement cost by evaluating recently published data and adjusting replacement cost for physical deterioration, functional and economic obsolescence. We used the market approach to measure the value of certain assets through an analysis of recent sales or offerings of comparable properties.

The fair value of customer relationships was based on the income approach. Key assumptions in the income approach include projected revenue attributable to customer relationships, operating margins and discount rates.

The fair values discussed above were based on significant inputs that are not observable in the market and, therefore, represent Level 3 measurements.

The fair values of all other current assets and liabilities were equivalent to their carrying values due to their short-term nature.

The goodwill recognized in the Delaware Gathering Acquisition is primarily attributable to enhancing our third-party revenues, further diversification of our customer and product mix, expanding our footprint into the Delaware basin and bolstering our Environmental, Social and Governance ("ESG") optionality through furthering carbon capture opportunities and greenhouse gas reduction projects currently underway. This goodwill is deductible for income tax purposes. Goodwill related to the Delaware Gathering Acquisition is included in the logistics segment.


~~10 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

Unaudited Pro Forma Financial Information

The following table summarizes the unaudited pro forma financial information of the Company assuming the Delaware Gathering Acquisition had occurred on January 1, 2022. The unaudited pro forma financial information has been adjusted to give effect to certain pro forma adjustments that are directly related to the Delaware Gathering Acquisition based on available information and certain assumptions that management believes are factually supportable. The most significant pro forma adjustments relate to (i) incremental interest expense and amortization of deferred financing costs associated with revolving credit facility borrowings incurred in connection with the Delaware Gathering Acquisition, (ii) incremental depreciation resulting from the estimated fair values of acquired property, plant and equipment, (iii) incremental amortization resulting from the estimated fair values of acquired customer relationships intangible (iv) accounting policy alignment, and (v) transaction costs. The unaudited pro forma financial information excludes any expected cost savings or other synergies as a result of the Delaware Gathering Acquisition. The unaudited pro forma financial information is not necessarily indicative of the results of operations that would have been achieved had the Delaware Gathering Acquisition been effective as of the dates presented, nor is it indicative of future operating results of the combined company. Actual results may differ significantly from the unaudited pro forma financial information.


		Three Months Ended June 30, 2022			Six Months Ended June 30, 2022				Three Months Ended September 30, 2022			Nine Months Ended September 30, 2022
(in millions, except per share data)	(in millions, except per share data)							(in millions, except per share data)
Net sales	Net sales		$	6,030.8		$	10,540.3	Net sales		$	5,324.9		$	15,865.2
Net income attributable to Delek	Net income attributable to Delek		$	363.5		$	364.0	Net income attributable to Delek		$	10.1		$	374.1
Net income per share:	Net income per share:							Net income per share:
Basic income per share	Basic income per share		$	5.13		$	5.05	Basic income per share		$	0.14		$	5.23
Diluted income per share	Diluted income per share		$	5.07		$	5.01	Diluted income per share		$	0.14		$	5.19

3. Segment Data

We aggregate our operating units into three reportable segments: Refining, Logistics, and Retail. Operations that are not specifically included in the reportable segments are included in Corporate, Other and Eliminations, which consist of the following:

•our corporate activities;

•results of certain immaterial operating segments, including our Canadian crude trading operations (as discussed in Note 10); and

•intercompany eliminations.

The disaggregated financial results for the reporting segments have been prepared using a management approach, which is consistent with the basis and manner in which management internally disaggregates financial information for the purposes of assisting internal operating decisions. The CODM evaluates performance based upon EBITDA attributable to Delek. We define EBITDA attributable to Delek for any period as net income (loss) attributable to Delek plus interest expense, income tax expense (benefit), depreciation and amortization. Segment EBITDA should not be considered a substitute for results prepared in accordance with U.S. GAAP and should not be considered alternatives to net income (loss), which is the most directly comparable financial measure to EBITDA that is in accordance with U.S. GAAP. Segment EBITDA, as determined and measured by us, should also not be compared to similarly titled measures reported by other companies.


11 \|

Notes to Condensed Financial Statements (Unaudited)

Assets by segment are not a measure used to assess the performance of the Company by the CODM and thus are not disclosed.

Refining Segment

The refining segment processes crude oil and other feedstocks for the manufacture of transportation motor fuels, including various grades of gasoline, diesel fuel and aviation fuel, asphalt and other petroleum-based products that are distributed through owned and third-party product terminals. The refining segment has a combined nameplate capacity of 302,000 barrels per day ("bpd") as of ~~June~~September 30, 2023, including the following:

•Tyler, Texas refinery (the "Tyler refinery");

•El Dorado, Arkansas refinery (the "El Dorado refinery");

•Big Spring, Texas refinery (the "Big Spring refinery"); and

•Krotz Springs, Louisiana refinery (the "Krotz Springs refinery").

The refining segment also owns and operates three biodiesel facilities involved in the production of biodiesel fuels and related activities, located in Crossett, Arkansas, Cleburne, Texas and New Albany, Mississippi.


~~11 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

Logistics Segment

Our logistics segment owns and operates crude oil, refined products and natural gas logistics and marketing assets as well as water disposal and recycling assets. The logistics segment generates revenue by charging fees for gathering, transporting and storing crude oil and natural gas, marketing, distributing, transporting and storing intermediate and refined products and disposing and recycling water in select regions of the southeastern United States, the Delaware Basin in New Mexico and West Texas for our refining segment and third parties, and sales of wholesale products in the West Texas market. The operating results and assets acquired in the Delaware Gathering Acquisition have been included in the logistics segment since June 1, 2022.

Retail Segment

Our retail segment consists of ~~247~~250 owned and leased convenience store sites as of ~~June~~September 30, 2023, located primarily in West Texas and New Mexico. These convenience stores typically offer various grades of fuel, food and beverage products, general merchandise, and certain food and other services. Substantially all of the motor fuel sold through our retail segment is supplied by our Big Spring refinery.

Business Segment Operating Performance

The following is a summary of business segment operating performance as measured by EBITDA attributable to Delek for the period indicated (in millions):

Three Months Ended June 30, 2023
(In millions) Refining Logistics Retail Corporate,
Other and Eliminations Consolidated
Net revenues (excluding intercompany fees and revenues) $ 3,849.0 $ 113.9 $ 232.7 $ — $ 4,195.6
Inter-segment fees and revenues 203.5 133.0 — (336.5) —
Total revenues $ 4,052.5 $ 246.9 $ 232.7 $ (336.5) $ 4,195.6
Segment EBITDA attributable to Delek $ 110.5 $ 90.9 $ 15.0 $ (58.7) $ 157.7
Depreciation and amortization (59.8) (23.7) (2.6) (3.3) (89.4)
Interest expense, net (12.2) (35.0) — (33.2) (80.4)
Income tax benefit 3.8
Net loss attributable to Delek $ (8.3)
Capital spending (excluding business combinations) $ 29.5 $ 19.4 $ 5.3 $ 7.0 $ 61.2

Three Months Ended June 30, 2022
(In millions) Refining Logistics Retail Corporate,
Other and Eliminations Consolidated
Net revenues (excluding intercompany fees and revenues) $ 5,562.6 $ 142.4 $ 277.1 $ 0.5 $ 5,982.6
Inter-segment fees and revenues 312.3 124.3 — (436.6) —
Total revenues $ 5,874.9 $ 266.7 $ 277.1 $ (436.1) $ 5,982.6
Segment EBITDA attributable to Delek $ 587.9 $ 62.6 $ 12.5 $ (89.2) $ 573.8
Depreciation and amortization (49.9) (13.3) (3.2) (1.6) (68.0)
Interest expense, net (1.7) (16.8) — (25.1) (43.6)
Income tax expense (100.4)
Net income attributable to Delek $ 361.8
Capital spending (excluding business combinations) $ 19.0 $ 26.7 $ 6.0 $ 8.7 $ 60.4


	Three Months Ended September 30, 2023
(In millions)	Refining		Logistics		Retail		Corporate, Other and Eliminations		Consolidated
Net revenues (excluding intercompany fees and revenues)	$	4,392.4	$	119.5	$	236.5	$	—	$	4,748.4
Inter-segment fees and revenues	232.1		156.4		—		(388.5)		—
Total revenues	$	4,624.5	$	275.9	$	236.5	$	(388.5)	$	4,748.4

Segment EBITDA attributable to Delek	$	285.1	$	96.5	$	16.2	$	(64.0)	$	333.8
Depreciation and amortization	(60.1)		(24.6)		(3.6)		(3.0)		(91.3)
Interest expense, net	(12.0)		(37.0)		0.1		(33.4)		(82.3)
Income tax expense									(31.5)
Net income attributable to Delek									$	128.7

Income from equity method investments	$	0.2	$	9.3	$	—	$	17.5	$	27.0
Capital spending (excluding business combinations)	$	20.2	$	13.1	$	8.0	$	7.0	$	48.3


12 \|

Notes to Condensed Financial Statements (Unaudited)


		Six Months Ended June 30, 2023											Three Months Ended September 30, 2022
(In millions)	(In millions)	Refining		Logistics		Retail		Corporate, Other and Eliminations		Consolidated		(In millions)	Refining		Logistics		Retail		Corporate, Other and Eliminations		Consolidated
Net revenues (excluding intercompany fees and revenues)	Net revenues (excluding intercompany fees and revenues)	$	7,449.8	$	232.4	$	437.7	$	—	$	8,119.9	Net revenues (excluding intercompany fees and revenues)	$	4,904.5	$	166.9	$	253.1	$	0.4	$	5,324.9
Inter-segment fees and revenues	Inter-segment fees and revenues	397.2		258.0		—		(655.2)		—		Inter-segment fees and revenues	262.9		127.2		—		(390.1)		—
Total revenues	Total revenues	$	7,847.0	$	490.4	$	437.7	$	(655.2)	$	8,119.9	Total revenues	$	5,167.4	$	294.1	$	253.1	$	(389.7)	$	5,324.9

Segment EBITDA attributable to Delek	Segment EBITDA attributable to Delek	$	302.6	$	182.3	$	21.4	$	(108.6)	$	397.7	Segment EBITDA attributable to Delek	$	90.3	$	87.3	$	13.5	$	(56.1)	$	135.0
Depreciation and amortization	Depreciation and amortization	(116.4)		(44.8)		(5.3)		(6.3)		(172.8)		Depreciation and amortization	(49.2)		(19.6)		(2.6)		(1.5)		(72.9)
Interest expense, net	Interest expense, net	(21.2)		(67.6)		(0.2)		(67.9)		(156.9)		Interest expense, net	(0.2)		(22.6)		—		(27.9)		(50.7)
Income tax expense	Income tax expense									(12.0)		Income tax expense									(4.0)
Net income attributable to Delek	Net income attributable to Delek									$	56.0	Net income attributable to Delek									$	7.4

Income from equity method investments												Income from equity method investments	$	0.1	$	8.6	$	—	$	9.1	$	17.8
Capital spending (excluding business combinations)	Capital spending (excluding business combinations)	$	177.1	$	55.5	$	8.0	$	12.7	$	253.3	Capital spending (excluding business combinations)	$	22.7	$	32.2	$	13.6	$	12.3	$	80.8

Six Months Ended June 30, 2022
(In millions) Refining Logistics Retail Corporate,
Other and Eliminations Consolidated
Net revenues (excluding intercompany fees and revenues) $ 9,729.1 $ 225.2 $ 486.6 $ 0.8 $ 10,441.7
Inter-segment fees and revenues 538.1 248.1 — (786.2) —
Total revenues $ 10,267.2 $ 473.3 $ 486.6 $ (785.4) $ 10,441.7
Segment EBITDA attributable to Delek $ 667.9 $ 126.8 $ 22.8 $ (127.3) $ 690.2
Depreciation and amortization (102.7) (23.7) (6.7) (3.2) (136.3)
Interest expense, net (2.3) (31.0) — (48.7) (82.0)
Income tax expense (103.5)
Net income attributable to Delek $ 368.4
Capital spending (excluding business combinations) $ 33.3 $ 35.8 $ 9.0 $ 15.2 $ 93.3


	Nine Months Ended September 30, 2023
(In millions)	Refining		Logistics		Retail		Corporate, Other and Eliminations		Consolidated
Net revenues (excluding intercompany fees and revenues)	$	11,842.2	$	351.9	$	674.2	$	—	$	12,868.3
Inter-segment fees and revenues	629.3		414.4		—		(1,043.7)		—
Total revenues	$	12,471.5	$	766.3	$	674.2	$	(1,043.7)	$	12,868.3

Segment EBITDA attributable to Delek	$	587.7	$	278.8	$	37.6	$	(172.6)	$	731.5
Depreciation and amortization	(176.5)		(69.4)		(8.9)		(9.3)		(264.1)
Interest expense, net	(33.2)		(104.6)		(0.1)		(101.3)		(239.2)
Income tax expense									(43.5)
Net income attributable to Delek									$	184.7

Income from equity method investments	$	0.7	$	22.9	$	—	$	43.5	$	67.1
Capital spending (excluding business combinations)	$	197.3	$	68.6	$	16.0	$	19.7	$	301.6


	Nine Months Ended September 30, 2022
(In millions)	Refining		Logistics		Retail		Corporate, Other and Eliminations		Consolidated
Net revenues (excluding intercompany fees and revenues)	$	14,633.6	$	392.1	$	739.7	$	1.2	$	15,766.6
Inter-segment fees and revenues	801.0		375.3		—		(1,176.3)		—
Total revenues	$	15,434.6	$	767.4	$	739.7	$	(1,175.1)	$	15,766.6

Segment EBITDA attributable to Delek	$	758.2	$	214.1	$	36.3	$	(183.4)	$	825.2
Depreciation and amortization	(151.9)		(43.3)		(9.3)		(4.7)		(209.2)
Interest expense, net	(2.5)		(53.6)		—		(76.6)		(132.7)
Income tax expense									(107.5)
Net income attributable to Delek									$	375.8

Income from equity method investments	$	0.5	$	22.7	$	—	$	21.2	$	44.4
Capital spending (excluding business combinations)	$	56.0	$	68.0	$	22.6	$	27.5	$	174.1


13 \|

Notes to Condensed Financial Statements (Unaudited)

4. Earnings Per Share

Basic earnings per share (or "EPS") is computed by dividing net income by the weighted average common shares outstanding. Diluted earnings per share is computed by dividing net income, 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 be dilutive), and is inclusive of awards disclosed in Note 16 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.


~~13 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

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


		Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022				2023		2022		2023		2022
Numerator:	Numerator:										Numerator:
Numerator for EPS	Numerator for EPS										Numerator for EPS
Net (loss) income		$	(1.5)	$	368.6	$	70.7	$	383.4
Net income											Net income	$	136.1	$	16.8	$	206.8	$	400.2
Less: Income attributed to non-controlling interest	Less: Income attributed to non-controlling interest	6.8		6.8		14.7		15.0			Less: Income attributed to non-controlling interest	7.4		9.4		22.1		24.4

Numerator for basic and diluted EPS attributable to Delek	Numerator for basic and diluted EPS attributable to Delek	$	(8.3)	$	361.8	$	56.0	$	368.4		Numerator for basic and diluted EPS attributable to Delek	$	128.7	$	7.4	$	184.7	$	375.8

Denominator:	Denominator:										Denominator:
Weighted average common shares outstanding (denominator for basic EPS)	Weighted average common shares outstanding (denominator for basic EPS)	65,773,609		70,805,458		66,359,537		72,014,151			Weighted average common shares outstanding (denominator for basic EPS)	64,889,504		70,471,645		65,864,141		71,494,332

Dilutive effect of stock-based awards	Dilutive effect of stock-based awards	—		874,496		475,785		661,162			Dilutive effect of stock-based awards	575,466		637,719		508,194		654,306
Weighted average common shares outstanding, assuming dilution (denominator for diluted EPS)	Weighted average common shares outstanding, assuming dilution (denominator for diluted EPS)	65,773,609		71,679,954		66,835,322		72,675,313			Weighted average common shares outstanding, assuming dilution (denominator for diluted EPS)	65,464,970		71,109,364		66,372,335		72,148,638

EPS:	EPS:										EPS:

Basic (loss) income per share		$	(0.13)	$	5.11	$	0.84	$	5.12
Basic income per share											Basic income per share	$	1.98	$	0.11	$	2.80	$	5.26

Diluted (loss) income per share		$	(0.13)	$	5.05	$	0.84	$	5.07
Diluted income per share											Diluted income per share	$	1.97	$	0.10	$	2.78	$	5.21

The following equity instruments were excluded from the diluted weighted average common shares outstanding because their effect would be anti-dilutive:	The following equity instruments were excluded from the diluted weighted average common shares outstanding because their effect would be anti-dilutive:										The following equity instruments were excluded from the diluted weighted average common shares outstanding because their effect would be anti-dilutive:
Antidilutive stock-based compensation (because average share price is less than exercise price)	Antidilutive stock-based compensation (because average share price is less than exercise price)	2,572,768		1,450,184		2,149,803		2,853,904			Antidilutive stock-based compensation (because average share price is less than exercise price)	1,254,610		2,138,130		1,756,314		2,380,376
Antidilutive due to loss		464,170		—		—		—
Total antidilutive stock-based compensation		3,036,938		1,450,184		2,149,803		2,853,904

5. Delek Logistics

Delek Logistics is a publicly traded limited partnership formed by Delek in 2012 that owns and operates crude oil, refined products and natural gas logistics and marketing assets as well as water disposal and recycling assets. A substantial majority of Delek Logistics' assets are integral to Delek’s refining and marketing operations. As of ~~June~~September 30, 2023, we owned a 78.7% interest in Delek Logistics, consisting of 34,311,278 common limited partner units and the non-economic general partner interest. The limited partner interests in Delek Logistics not owned by us are reflected in net income attributable to non-controlling interest in the accompanying consolidated statements of income and in non-controlling interest in subsidiaries in the accompanying consolidated balance sheets.

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. The revenues and expenses associated with these agreements are eliminated in consolidation.

Delek Logistics is a VIE, as defined under GAAP, and is consolidated into our consolidated financial statements, representing our logistics segment. The assets of Delek Logistics can only be used to settle its own obligations and its creditors have no recourse to our assets. Exclusive of intercompany balances and the marketing agreement intangible asset between Delek Logistics and Delek which are eliminated in consolidation, the Delek Logistics condensed consolidated balance sheets are included in the condensed consolidated balance sheets of Delek. The Delek Logistics condensed consolidated balance sheets are presented below (in millions):


14 \|

Notes to Condensed Financial Statements (Unaudited)


		As of June 30, 2023		As of December 31, 2022			As of September 30, 2023		As of December 31, 2022
ASSETS	ASSETS					ASSETS
Cash and cash equivalents	Cash and cash equivalents	$	7.7	$	8.0	Cash and cash equivalents	$	4.2	$	8.0
Accounts receivable	Accounts receivable	65.9		53.3		Accounts receivable	41.2		53.3
Accounts receivable from related parties	Accounts receivable from related parties	7.4		—		Accounts receivable from related parties	67.1		—
Inventory	Inventory	3.1		1.5		Inventory	4.1		1.5
Other current assets	Other current assets	1.4		2.4		Other current assets	1.0		2.4
Property, plant and equipment, net	Property, plant and equipment, net	941.7		924.0		Property, plant and equipment, net	936.7		924.0
Equity method investments	Equity method investments	242.7		257.0		Equity method investments	241.9		257.0
Operating lease right-of-use assets	Operating lease right-of-use assets	22.6		24.8		Operating lease right-of-use assets	21.0		24.8
Goodwill	Goodwill	27.1		27.1		Goodwill	27.1		27.1
Intangible assets, net	Intangible assets, net	353.2		364.8		Intangible assets, net	347.9		364.8
Other non-current assets	Other non-current assets	19.8		16.4		Other non-current assets	17.3		16.4
Total assets	Total assets	$	1,692.6	$	1,679.3	Total assets	$	1,709.5	$	1,679.3
LIABILITIES AND DEFICIT	LIABILITIES AND DEFICIT					LIABILITIES AND DEFICIT
Accounts payable	Accounts payable	$	14.5	$	57.4	Accounts payable	$	28.0	$	57.4
Accounts payable to related parties	Accounts payable to related parties	—		6.1		Accounts payable to related parties	—		6.1
Current portion of long-term debt	Current portion of long-term debt	15.0		15.0		Current portion of long-term debt	15.0		15.0
Current portion of operating lease liabilities	Current portion of operating lease liabilities	8.2		8.0		Current portion of operating lease liabilities	8.1		8.0
Accrued expenses and other current liabilities	Accrued expenses and other current liabilities	18.8		19.7		Accrued expenses and other current liabilities	34.3		19.7
Long-term debt	Long-term debt	1,729.3		1,646.6		Long-term debt	1,726.4		1,646.6
Asset retirement obligations	Asset retirement obligations	9.7		9.3		Asset retirement obligations	9.9		9.3
Operating lease liabilities, net of current portion	Operating lease liabilities, net of current portion	10.5		12.1		Operating lease liabilities, net of current portion	9.2		12.1
Other non-current liabilities	Other non-current liabilities	16.1		15.8		Other non-current liabilities	17.8		15.8
Deficit	Deficit	(129.5)		(110.7)		Deficit	(139.2)		(110.7)
Total liabilities and deficit	Total liabilities and deficit	$	1,692.6	$	1,679.3	Total liabilities and deficit	$	1,709.5	$	1,679.3

6. Equity Method Investments

Wink to Webster Pipeline

Through our wholly-owned direct subsidiary Delek Energy, we own a 50% investment in W2W Holdings LLC ("HoldCo") which was formed by us and MPLX Operations LLC ("MPLX") to obtain financing and fund capital calls associated with our collective and contributed interests in the Wink to Webster Pipeline LLC ("WWP") Joint Venture. The Company has determined that HoldCo is a VIE. While we have the ability to exert significant influence through participation in board and management committees, we are not the primary beneficiary since we do not have a controlling financial interest in HoldCo, and no single party has the power to direct the activities that most significantly impact HoldCo's economic performance. We account for HoldCo using the equity method of accounting.

On June 2, 2022, HoldCo's wholly-owned finance LLC ("WWP Project Financing JV") refinanced its project finance debt using the proceeds from a $535.0 million senior secured notes issuance due January 31, 2032. In connection with this notes issuance, on June 2, 2022 the WWP Project Financing JV also entered into a senior secured credit agreement that provides for revolving loan commitments in an amount of up to $75.0 million and the issuance of letters of credit in an amount of up to $44.0 million. The maturity date of the revolver and letter credit commitments is June 2, 2027. Distributions received from WWP are first applied to service the WWP Project Financing JV debt, with excess distributions being made to the HoldCo members as provided for in the W2W Holdings LLC Agreement and as allowed for under its debt agreements. The obligations of the HoldCo members under the W2W Holdings LLC Agreement are guaranteed by the parents of the member entities.

As of ~~June~~September 30, 2023, except for the guarantee of member obligations under the joint venture, we do not have other guarantees with or to HoldCo, nor any third-party associated with HoldCo contracted work. The Company's maximum exposure to any losses incurred by HoldCo is limited to its investment. As of ~~June~~September 30, 2023 and December 31, 2022, Delek's HoldCo investment balance totaled ~~$55.0~~$56.2 million and $49.0 million, respectively, and is included in total assets in corporate, other and eliminations in our segment disclosure. In addition, on the investment, we recognized income of ~~$6.8~~$6.9 million and ~~$11.3~~$18.2 million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$2.1~~$1.2 million and ~~$4.2~~$5.4 million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.


15 \|

Notes to Condensed Financial Statements (Unaudited)

Delek Logistics Investments

Delek Logistics has a 33% membership interest in Red River Pipeline Company LLC (“Red River”), which owns a 16-inch crude oil pipeline running from Cushing, Oklahoma to Longview, Texas. As of ~~June~~September 30, 2023 and December 31, 2022, Delek's investment balance in Red River totaled $140.9 million and $149.6 million, respectively. We recognized income on the investment totaling ~~$4.0~~$5.5 million and ~~$7.8~~$13.3 million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$4.6~~$4.7 million and ~~$9.9~~$14.6 million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively. This investment is accounted for using the equity method and is included as part of total assets in our logistics segment.

In addition to Red River, Delek Logistics has two other joint ventures that own and operate logistics assets, and which serve third parties and subsidiaries of Delek. We own a 50% membership interest in the entity formed with an affiliate of Plains All American Pipeline, L.P. to operate one of these pipeline systems (the "Caddo Pipeline") and a 33% membership interest in Andeavor Logistics Rio Pipeline LLC which operates the other pipeline system (the "Rio Pipeline"). As of ~~June~~September 30, 2023 and December 31, 2022, Delek Logistics' investment balance in these joint ventures was ~~$101.8~~$101.0 million and $107.4 million, respectively, and are accounted for using the equity method. We recognized income on these investments totaling ~~$3.3~~$3.8 million and ~~$5.8~~$9.6 million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$2.4~~$3.9 million and ~~$4.2~~$8.1 million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.

Other Investments

In addition to our pipeline joint ventures, we also have a 50% interest in a joint venture that owns asphalt terminals located in the southwestern region of the U.S., as well as a 50% interest in a joint venture that owns, operates and maintains a terminal consisting of an ethanol unit train facility with an ethanol tank in Arkansas. As of ~~June~~September 30, 2023 and December 31, 2022, Delek's investment balance in these joint ventures was ~~$65.9~~$73.1 million and $53.7 million, respectively. We recognized income on these investments totaling ~~$11.4~~$10.8 million and ~~$15.2~~$26.0 million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$6.6~~$8.0 million and ~~$8.3~~$16.3 million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively. Both investments are accounted for using the equity method. The investment in asphalt terminal operations is included as part of total assets in corporate, other and eliminations in our segment disclosure while the ethanol terminal operations is reflected in the refining segment.

Combined summarized financial information for our equity method investees ~~(with the exception of our interest in a joint venture that owns asphalt terminals)~~ on a 100% basis is shown below (in millions):


		As of June 30, 2023		As of December 31, 2022			As of September 30, 2023		As of December 31, 2022
Current assets	Current assets	$	70.3	$	54.5	Current assets	$	184.5	$	54.5
Non-current assets	Non-current assets	$	1,283.4	$	1,275.1	Non-current assets	$	1,344.4	$	1,275.1
Current liabilities	Current liabilities	$	33.6	$	8.3	Current liabilities	$	61.1	$	8.3
Non-current liabilities	Non-current liabilities	$	551.0	$	548.5	Non-current liabilities	$	552.3	$	548.5

Three Months Ended June 30, Six Months Ended June 30,
2023 2022 2023 2022
Revenues $ 32.0 $ 34.9 $ 63.7 $ 72.1
Gross profit $ 19.9 $ 22.7 $ 39.6 $ 47.9
Operating income $ 19.6 $ 21.6 $ 37.9 $ 46.0
Net income $ 32.9 $ 19.0 $ 57.6 $ 41.5

~~Summarized financial information for our interest in a joint venture that owns asphalt terminals on a 100% basis is shown below (in millions):~~


		Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022				2023		2022		2023		2022
Revenues	Revenues	$	103.8	$	71.2	$	157.0	$	100.1		Revenues	$	151.4	$	162.6	$	373.1	$	334.8
Gross profit	Gross profit	$	27.3	$	16.5	$	37.9	$	22.3		Gross profit	$	54.5	$	53.5	$	132.8	$	123.7
Operating income	Operating income	$	22.2	$	12.6	$	28.7	$	15.4		Operating income	$	47.9	$	46.6	$	114.5	$	107.9
Net income	Net income	$	22.3	$	12.8	$	29.1	$	15.6		Net income	$	61.9	$	40.1	$	148.6	$	97.3

7. Inventory

Crude oil feedstocks, refined products, blendstocks and asphalt inventory for all of our operations, excluding merchandise inventory in our retail segment, are stated at the lower of cost determined using ~~FIFO~~the first-in, first-out ("FIFO") basis or net realizable value. 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.


16 \|

Notes to Condensed Financial Statements (Unaudited)

The following table presents the components of inventory for each period presented:


		Titled Inventory		Inventory Intermediation Agreement (1)		Total			Titled Inventory		Inventory Intermediation Agreement (1)		Total
June 30, 2023
September 30, 2023								September 30, 2023
Feedstocks, raw materials and supplies	Feedstocks, raw materials and supplies	$	475.9	$	143.7	$	619.6	Feedstocks, raw materials and supplies	$	371.6	$	156.7	$	528.3
Refined products and blendstock	Refined products and blendstock	321.2		303.6		624.8		Refined products and blendstock	283.7		335.2		618.9
Merchandise inventory and other	Merchandise inventory and other	32.0		—		32.0		Merchandise inventory and other	32.0		—		32.0
Total	Total	$	829.1	$	447.3	$	1,276.4	Total	$	687.3	$	491.9	$	1,179.2

December 31, 2022	December 31, 2022							December 31, 2022
Feedstocks, raw materials and supplies	Feedstocks, raw materials and supplies	$	479.7	$	163.8	$	643.5	Feedstocks, raw materials and supplies	$	479.7	$	163.8	$	643.5
Refined products and blendstock	Refined products and blendstock	490.8		354.8		845.6		Refined products and blendstock	490.8		354.8		845.6
Merchandise inventory and other	Merchandise inventory and other	29.4		—		29.4		Merchandise inventory and other	29.4		—		29.4
Total	Total	$	999.9	$	518.6	$	1,518.5	Total	$	999.9	$	518.6	$	1,518.5

(1) Refer to Note 8 - Inventory Intermediation Obligations for further information.

At ~~June~~September 30, 2023, we recorded a pre-tax inventory valuation reserve of ~~$1.6~~$5.0 million due to a market price decline below our cost of certain inventory products. At December 31, 2022, we recorded a pre-tax inventory valuation reserve of $11.2 million. We recognized a net reduction (increase) in cost of materials and other in the accompanying condensed consolidated statements of income related to the change in pre-tax inventory valuation of ~~$7.9~~$(3.4) million and ~~$9.6~~$6.2 million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$(7.3)~~$(20.3) million and ~~$1.2~~$(19.1) million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.

For the three months ended June 30, 2023, we recorded an immaterial cumulative error correction of approximately $8.0 million, which was reflected as an adjustment to total cost of sales. This adjustment related to spare parts that should have been included in inventories. The impact of the balance sheet error correction would not have been material to any prior period financial statements and is not material to inventories or total cost of sales in the current period.

8. Inventory Intermediation Obligations

The following table summarizes our outstanding obligations under our Inventory Intermediation Agreement and Supply and Offtake Agreements:


		As of June 30, 2023		As of December 31, 2022			As of September 30, 2023		As of December 31, 2022
Obligations under Inventory Intermediation Agreement	Obligations under Inventory Intermediation Agreement					Obligations under Inventory Intermediation Agreement
Obligations related to Base Layer Volumes	Obligations related to Base Layer Volumes	$	453.4	$	491.8	Obligations related to Base Layer Volumes	$	502.2	$	491.8
Current portion	Current portion	—		49.9		Current portion	—		49.9
Total obligations under Inventory Intermediation Agreement	Total obligations under Inventory Intermediation Agreement	$	453.4	$	541.7	Total obligations under Inventory Intermediation Agreement	$	502.2	$	541.7
Other (receivable) payable for monthly activity true-up	Other (receivable) payable for monthly activity true-up	$	(12.4)	$	5.6	Other (receivable) payable for monthly activity true-up	$	(11.7)	$	5.6
Obligations under Supply and Offtake Agreements	Obligations under Supply and Offtake Agreements					Obligations under Supply and Offtake Agreements

Other (receivable) payable for monthly activity true-up	Other (receivable) payable for monthly activity true-up	$	—	$	(34.9)	Other (receivable) payable for monthly activity true-up	$	—	$	(34.9)

Included in the Inventory Intermediation Agreement and Supply and Offtake Agreements are cost of financing associated with the value of the inventory and other periodic charges, which we include in interest expense, net in the condensed consolidated statements of income. In addition to the cost of financing charges, we have other intermediation fees which include market structure settlements, where we may pay or receive amounts based on market conditions and volumes subject to the intermediation agreement. These market structure settlements are recorded in cost of materials and other in the condensed consolidated statements of income. The following table summarizes these fees:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022			2023		2022		2023		2022
Net fees and expenses:	Net fees and expenses:									Net fees and expenses:

Inventory intermediation fees	Inventory intermediation fees	$	7.6	$	18.6	$	13.5	$	37.7	Inventory intermediation fees	$	58.3	$	16.4	$	71.8	$	54.1
Interest expense, net	Interest expense, net	$	15.6	$	5.2	$	29.6	$	10.2	Interest expense, net	$	16.5	$	5.9	$	46.1	$	16.1

Inventory Intermediation Agreement

On December 22, 2022, Delek entered into an inventory intermediation agreement ("Inventory Intermediation Agreement") with Citigroup Energy Inc. ("Citi") in connection with DK Trading & Supply, LLC ("DKTS"), an indirect subsidiary of Delek. Pursuant to the Inventory Intermediation Agreement, Citi will (i) purchase from and sell to DKTS crude oil and other petroleum feedstocks in connection with refining processing operations at El Dorado, Big Spring, and Krotz Springs, (ii) purchase from and sell to DKTS all refined products produced by such refineries other than certain excluded products and (iii) in connection with such purchases and sales, DKTS will enter into certain market risk


~~17 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

hedges in each case, on the terms and subject to certain conditions. The Inventory Intermediation Agreement results in up to $800 million of working capital capacity for DKTS. The Inventory Intermediation Agreement expires December 30, 2024, subject to an extension that can be executed by Citi for an additional twelve months. Prior to December 30, 2022, Delek had Supply and Offtake Agreements (the "Supply and Offtake Agreements" or the "J. Aron Agreements") with J. Aron & Company ("J. Aron"). The Inventory Intermediation Agreement replaced the Supply and Offtake Agreements that expired on December 30, 2022.


17 \|

Notes to Condensed Financial Statements (Unaudited)

On ~~June 21,~~September 18, 2023, DKTS entered into a letter agreement to the Inventory Intermediation Agreement with Citi to temporarily increase its letter of credit issued to Citi by ~~$100.0~~$180.0 million which ~~will allow~~allowed DKTS to defer payments of certain obligations under the Inventory Intermediation Agreement until ~~July~~October 2023. These deferred obligations ~~will be~~were subject to applicable interest charges. As of ~~June~~September 30, 2023, we had letters of credit outstanding of ~~$195.0~~$260.0 million supporting the Inventory Intermediation Agreement.

The Inventory Intermediation Agreement provides for the lease to Citi of crude oil and refined product storage facilities. At the inception of the Inventory Intermediation Agreement, we transferred title to a certain number of barrels of crude and other inventories to Citi, and the Inventory Intermediation Agreement requires the repurchase of the remaining inventory (including certain "Base Layer Volumes") at termination. As of ~~June~~September 30, 2023 and December 31, 2022, the volumes subject to the Inventory Intermediation Agreement totaled ~~5.8~~5.4 million barrels and 6.3 million barrels, including Base Layer Volumes associated with our non-current inventory intermediation obligation of 5.5 million barrels.

The Inventory Intermediation Agreement is accounted for as an inventory financing arrangement under the fair value election provided by ASC 815 Derivatives and Hedging ("ASC 815") and ASC 825, Financial Instruments ("ASC 825"). Therefore, the crude oil and refined products barrels subject to the Inventory Intermediation Agreement will continue to be reported in our condensed consolidated balance sheets until processed and sold to a third party. At each reporting period, we record a liability equal to the repurchase obligation to Citi at current market prices. The repurchase obligations associated with the Base Layer Volumes are reflected as non-current liabilities on our condensed consolidated balance sheet to the extent that they are not contractually due within twelve months. The remaining obligation resulting from our monthly activity, including long and short inventory positions valued at market-indexed pricing, are included in current liabilities (or receivables) on our condensed consolidated balance sheet.

Gains (losses) related to changes in fair value due to commodity-index price are recorded as a component of cost of materials and other in the condensed consolidated statements of income. With respect to the repurchase obligation, we recognized ~~gains~~losses attributable to changes in fair value due to commodity-index price totaling ~~$26.3~~$83.5 million and ~~$39.0~~$44.5 million during the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively.

Supply & Offtake Agreements

Prior to December 30, 2022, Delek was a party to Supply and Offtake Agreements with J. Aron in connection with its El Dorado, Big Spring and Krotz Springs refineries. Pursuant to the 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 repurchase of Baseline Volumes at the end of the Supply and Offtake Agreement term (representing the "Baseline Step-Out Liability" or, collectively, the "Baseline Step-Out Liabilities") continued to be recorded at fair value under the fair value election included under ASC 815 and ASC 825. The Baseline Step-Out Liabilities had a floating component whose fair value reflected changes to commodity price risk with changes in fair value recorded in cost of materials. For the three and ~~six~~nine months ended ~~June~~September 30, 2022, we recognized gains (losses) in cost of materials and other attributable to changes in fair value due to commodity-index price totaling ~~$58.1~~$124.2 million and ~~$206.9~~$(82.6) million, respectively.

~~9. Long-Term Obligations~~

~~Outstanding borrowings under debt instruments are as follows (in millions):~~

June 30, 2023 December 31, 2022
Delek Revolving Credit Facility $ 150.0 $ 450.0
Delek Term Loan Credit Facility 945.3 950.0
Delek Logistics Revolving Facility 811.0 720.5
Delek Logistics Term Loan Facility 292.5 300.0
Delek Logistics 2025 Notes 250.0 250.0
Delek Logistics 2028 Notes 400.0 400.0
United Community Bank Revolver 25.0 50.0
Principle amount of long-term debt 2,873.8 3,120.5
Less: Unamortized discount and deferred financing costs (62.9) (66.8)
Total debt, net of unamortized discount and deferred financing costs 2,810.9 3,053.7
Less: Current portion of long-term debt 49.5 74.5
Long-term debt, net of current portion $ 2,761.4 $ 2,979.2


18 \|

Notes to Condensed Financial Statements (Unaudited)

9. Long-Term Obligations

Outstanding borrowings under debt instruments are as follows (in millions):


	September 30, 2023		December 31, 2022
Delek Revolving Credit Facility	$	0.3	$	450.0
Delek Term Loan Credit Facility	942.9		950.0
Delek Logistics Revolving Facility	811.2		720.5
Delek Logistics Term Loan Facility	288.7		300.0
Delek Logistics 2025 Notes	250.0		250.0
Delek Logistics 2028 Notes	400.0		400.0
United Community Bank Revolver	5.0		50.0
Principle amount of long-term debt	2,698.1		3,120.5
Less: Unamortized discount and deferred financing costs	(60.1)		(66.8)
Total debt, net of unamortized discount and deferred financing costs	2,638.0		3,053.7
Less: Current portion of long-term debt	29.5		74.5
Long-term debt, net of current portion	$	2,608.5	$	2,979.2

Delek Term Loan Credit Facility

The Delek Term Loan Credit Facility principal of $950.0 million was drawn on November 18, 2022 at a discount of 4.00%. This senior secured facility allows for $400.0 million in incremental loans subject to certain restrictions. Repayment terms include quarterly principal payments of $2.4 million with the balance of principal due on November 19, 2029. At Delek’s option, borrowings bear interest at either the Adjusted Term Secured Overnight Financing Rate ("SOFR") or base rate as defined by the agreement, plus an applicable margin of 2.50% per annum with respect to base rate borrowings and 3.50% per annum with respect to SOFR borrowings. At ~~June~~September 30, 2023 and December 31, 2022, the weighted average borrowing rate was approximately ~~8.70%~~8.92% and 7.92%; respectively. The effective interest rate was ~~9.95%~~10.16% as of ~~June~~September 30, 2023.

Delek Logistics Term Loan Facility

The Delek Logistics Term Loan Facility principal of $300.0 million was drawn on October 13, 2022. On November 6, 2023, Delek Logistics entered into a First Amendment, a Second Amendment and a Third Amendment to the Delek Logistics Credit Facility (together, the “Amendments”) to extend the maturity of the Term Loan Facility to April 15, 2025. In addition, the Amendments added a maturity acceleration clause which will accelerate the maturity of the Delek Logistics Term Loan Facility to 180 days prior to the stated maturity date of the Delek Logistics 2025 Notes if any of the Delek Logistics 2025 Notes remain outstanding on that date. This senior secured facility requires four quarterly amortization payments of $3.8 million in 2023, ~~and three~~four quarterly amortization payments of $7.5 million in 2024 and one quarterly amortization payment of $7.5 million in 2025with final maturity and principal due on ~~October 13, 2024.~~April 15, 2025. At Delek Logistics' option, borrowings bear interest at either the SOFR or U.S. dollar prime rate, plus an applicable margin. The applicable margin is 2.50% for the first year and 3.00% for the second year for U.S. dollar primate rate borrowings. SOFR borrowings include a credit spread adjustment of 0.10% to 0.25% plus an applicable margin of 3.50% for the first year and 4.00% for the second year. At ~~June~~September 30, 2023 and December 31, 2022, the weighted average borrowing rate was approximately ~~8.41%~~8.92% and 7.92%, respectively. The effective interest rate was ~~9.98%~~9.48% as of ~~June~~September 30, 2023.


19 \|

Notes to Condensed Financial Statements (Unaudited)

Revolving Credit Facilities

Available capacity and amounts outstanding for each of our revolving credit facilities as of ~~June~~September 30, 2023 are shown below (in millions):


		Total Capacity		Outstanding Borrowings		Outstanding Letters of Credit		Available Capacity		Maturity Date		Total Capacity		Outstanding Borrowings		Outstanding Letters of Credit		Available Capacity		Maturity Date
Delek Revolving Credit Facility (1)	Delek Revolving Credit Facility (1)	$	1,100.0	$	150.0	$	251.5	$	698.5	October 26, 2027	Delek Revolving Credit Facility (1)	$	1,100.0	$	0.3	$	301.6	$	798.1	October 26, 2027
Delek Logistics Revolving Facility (2)	Delek Logistics Revolving Facility (2)	$	900.0	$	811.0	$	—	$	89.0	October 13, 2027	Delek Logistics Revolving Facility (2)	$	900.0	$	811.2	$	—	$	88.8	October 13, 2027
United Community Bank Revolver (3)	United Community Bank Revolver (3)	$	25.0	$	25.0	$	—	$	—	June 30, 2024	United Community Bank Revolver (3)	$	25.0	$	5.0	$	—	$	20.0	June 30, 2024

(1) Total capacity includes letters of credit up to $500.0 million. This facility requires a quarterly unused commitment fee based on average commitment usage, currently at 0.30% per annum. Interest is measured at either the SOFR, base rate, or Canadian dollar bankers’ acceptances rate (“CDOR”), plus an applicable margin of 0.25% to 0.75% per annum with respect to base rate borrowings or 1.25% to 1.75% per annum with respect to SOFR and CDOR. As of June 30, 2023 and December 31, 2022, the weighted average interest rate was 6.45% and 5.67%, respectively.
(2) Total capacity includes letters of credit up to $115.0 million and $25.0 million for swing line loans. This facility requires a quarterly unused commitment fee based on average commitment usage, currently at 0.50% per annum. Interest is measured at either the U.S. dollar prime rate plus an applicable margin of 1.00% to 2.00% depending on Delek Logistics’ leverage ratio, or a SOFR rate plus a credit spread adjustment of 0.10% to 0.25% and an applicable margin ranging from 2.00% to 3.00% depending on the leverage ratio. As of June 30, 2023 and December 31, 2022, the weighted average interest rate was 7.95% and 7.55%, respectively.
(3) Requires a quarterly fee of 0.50% per year on the average unused revolving commitment. The weighted average borrowing rate as of June 30, 2023 and December 31, 2022 was 7.50% and 6.75%, respectively.
(1) Total capacity includes letters of credit up to $500.0 million. This facility requires a quarterly unused commitment fee based on average commitment usage, currently at 0.30% per annum. Interest is measured at either the SOFR, base rate, or Canadian dollar bankers’ acceptances rate (“CDOR”), plus an applicable margin of 0.25% to 0.75% per annum with respect to base rate borrowings or 1.25% to 1.75% per annum with respect to SOFR and CDOR. As of September 30, 2023 and December 31, 2022, the weighted average interest rate was 6.68% and 5.67%, respectively.											(1) Total capacity includes letters of credit up to $500.0 million. This facility requires a quarterly unused commitment fee based on average commitment usage, currently at 0.30% per annum. Interest is measured at either the SOFR, base rate, or Canadian dollar bankers’ acceptances rate (“CDOR”), plus an applicable margin of 0.25% to 0.75% per annum with respect to base rate borrowings or 1.25% to 1.75% per annum with respect to SOFR and CDOR. As of September 30, 2023 and December 31, 2022, the weighted average interest rate was 6.68% and 5.67%, respectively.
(2) The Delek Logistics Revolving Facility's maturity date will accelerate to 180 days prior to the stated maturity date of the Delek Logistics 2025 Notes if any of the Delek Logistics 2025 Notes remain outstanding on that date. Total capacity includes letters of credit up to $115.0 million and $25.0 million for swing line loans. This facility requires a quarterly unused commitment fee based on average commitment usage, currently at 0.50% per annum. Interest is measured at either the U.S. dollar prime rate plus an applicable margin of 1.00% to 2.00% depending on Delek Logistics’ leverage ratio, or a SOFR rate plus a credit spread adjustment of 0.10% to 0.25% and an applicable margin ranging from 2.00% to 3.00% depending on the leverage ratio. As of September 30, 2023 and December 31, 2022, the weighted average interest rate was 8.45% and 7.55%, respectively.											(2) The Delek Logistics Revolving Facility's maturity date will accelerate to 180 days prior to the stated maturity date of the Delek Logistics 2025 Notes if any of the Delek Logistics 2025 Notes remain outstanding on that date. Total capacity includes letters of credit up to $115.0 million and $25.0 million for swing line loans. This facility requires a quarterly unused commitment fee based on average commitment usage, currently at 0.50% per annum. Interest is measured at either the U.S. dollar prime rate plus an applicable margin of 1.00% to 2.00% depending on Delek Logistics’ leverage ratio, or a SOFR rate plus a credit spread adjustment of 0.10% to 0.25% and an applicable margin ranging from 2.00% to 3.00% depending on the leverage ratio. As of September 30, 2023 and December 31, 2022, the weighted average interest rate was 8.45% and 7.55%, respectively.
(3) Requires a quarterly fee of 0.50% per year on the average unused revolving commitment. The weighted average borrowing rate as of September 30, 2023 and December 31, 2022 was 7.75% and 6.75%, respectively.											(3) Requires a quarterly fee of 0.50% per year on the average unused revolving commitment. The weighted average borrowing rate as of September 30, 2023 and December 31, 2022 was 7.75% and 6.75%, respectively.

Delek Logistics Revolving Credit Facility

On November 6, 2023, Delek Logistics entered into the Amendments which among other things: (i) increased the U.S. Revolving Credit Commitments (as defined in the Delek Logistics Credit Facility) by an amount equal to $150.0 million, resulting in aggregate lender commitments under the Delek Logistics Revolving Credit Facility in an amount of $1.050 billion and (ii) increased the limit allowed for general unsecured debt (as defined in the Delek Logistics Credit Facility) by an amount equal to $95.0 million, resulting in an unsecured general debt limit of $150.0 million.

United Community Bank Revolver

On June 9, 2023, we amended the United Community Bank Revolver to reduce commitments from $50.0 million to $25.0 million and extended the maturity date to June 30, 2024.

Delek Logistics 2025 Notes

Our Delek Logistics 2025 Notes are general unsecured senior obligations comprised of $250.0 million in aggregate principal of 6.75% senior notes maturing on May 15, 2025. The Delek Logistics 2025 Notes are unconditionally guaranteed jointly and severally on a senior unsecured basis by Delek Logistics' existing subsidiaries (other than Finance Corp.) and will be unconditionally guaranteed on the same basis by certain of Delek Logistics' future subsidiaries. Interest is payable semi-annually in arrears on May 15 and November 15. As of ~~June~~September 30, 2023, the effective interest rate was ~~7.17%~~7.18%.

Delek Logistics 2028 Notes

Our Delek Logistics 2028 Notes are general unsecured senior obligations comprised of $400.0 million in aggregate principal amount of 7.125% senior notes maturing June 1, 2028. The Delek Logistics 2028 Notes are unconditionally guaranteed jointly and severally on a senior unsecured basis by Delek Logistics’ subsidiaries (other than Finance Corp.) and will be unconditionally guaranteed on the same basis by certain of Delek Logistics’ future subsidiaries. Interest is payable semi-annually in arrears on June 1 and December 1. As of ~~June~~September 30, 2023, the effective interest rate was 7.39%.


~~19 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

Guarantees Under Revolver and Term Facilities

The obligations of the borrowers under the Delek Term Loan Credit Facility and the Delek Revolving Credit Facility 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 Delek Term Loan Credit Facility and the Delek Revolving Credit Facility are also guaranteed by DK Canada Energy ULC, a British Columbia unlimited liability company and a wholly-owned restricted subsidiary of Delek.

The obligations under the Delek Logistics Revolving Facility and Term Loan Facility are secured by first priority liens on substantially all of Delek Logistics' tangible and intangible assets.


20 \|

Notes to Condensed Financial Statements (Unaudited)

Restrictive Terms and Covenants

Under the terms of our debt facilities, we are required to comply with usual and customary financial and non-financial covenants. Certain of our debt facilities contain limitations on future transactions such as incurrence of additional indebtedness, investments, affiliate transactions, asset acquisitions or dispositions, and dividends or distributions. As of ~~June~~September 30, 2023, we were in compliance with covenants on all of our debt instruments.

Some of Delek's subsidiaries have restrictions in their respective credit facilities limiting their use of assets. As of ~~June~~September 30, 2023, we had no subsidiaries with restricted net assets which would prohibit earnings from being transferred to the parent company for its use.

10. 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 our exposure to commodity price fluctuations on inventory above or below target levels (where appropriate) within each of our segments;

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

•managing our exposure to market crack spread fluctuations;

•managing the cost of ourRenewable Identification Numbers ("RINs") credits required by the U.S. Environmental Protection Agency ("EPA") to blend biofuels into fuel products ("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 swaps or caps to achieve these objectives. Futures contracts are standardized agreements, traded on a futures exchange, to buy or sell the commodity at a predetermined price and location at a specified future date. Options provide the right, but not the obligation to buy or sell a commodity at a specified price in the future. Commodity swaps 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/receipt 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.

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 ("NPNS") pursuant to ASC 815. If we elect the NPNS exception, such forward contracts are not accounted for as derivative instruments but rather are accounted for under other applicable GAAP. Commodity forward contracts accounted for as derivative instruments are recorded at fair value with changes in fair value recognized in earnings in the period of change. Our Canadian crude trading operations are accounted for as derivative instruments, and the related unrealized and realized gains and losses are recognized in other operating income, net on the condensed consolidated statements of income. Additionally, as of and for the three and ~~six~~nine months ended ~~June~~September 30, 2023, other forward contracts accounted for as derivatives that are specific to managing crude costs rather than for trading purposes are recognized in cost of materials and other on the condensed consolidated statements of income in our refining segment, and are included in our disclosures of commodity derivatives in the tables below.

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


~~20 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

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 RINs 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 RINs commitment contracts are recorded in cost of materials and other on the condensed consolidated statements of income. As of ~~June~~September 30, 2023, we do not believe there is any material credit risk with respect to the counterparties to any of our derivative contracts.

The following table presents the fair value of our derivative instruments as of ~~June~~September 30, 2023 and December 31, 2022. 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 11 for further information regarding the fair value of derivative instruments (in millions).

June 30, 2023 December 31, 2022
Derivative Type Balance Sheet Location Assets Liabilities Assets Liabilities
Derivatives not designated as hedging instruments:
Commodity derivatives (1)
Other current assets $ 181.5 $ (171.5) $ 217.1 $ (204.4)
Commodity derivatives (1)
Other current liabilities — (1.5) 101.0 (129.5)
Commodity derivatives (1)
Other long-term assets 1.3 (1.0) 1.1 (0.8)
RINs commitment contracts (2)
Other current assets 3.0 — 9.7 —
RINs commitment contracts (2)
Other current liabilities — (3.9) — (6.6)
Total gross fair value of derivatives 185.8 (177.9) 328.9 (341.3)
Less: Counterparty netting and cash collateral (3)
159.6 (172.5) 306.2 (320.0)
Total net fair value of derivatives $ 26.2 $ (5.4) $ 22.7 $ (21.3)


21 \|

Notes to Condensed Financial Statements (Unaudited)


		September 30, 2023				December 31, 2022
Derivative Type	Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
Derivatives not designated as hedging instruments:
Commodity derivatives (1)	Other current assets	$	116.9	$	(126.6)	$	217.1	$	(204.4)
Commodity derivatives (1)	Other current liabilities	19.5		(20.4)		101.0		(129.5)
Commodity derivatives (1)	Other long-term assets	0.6		(0.6)		1.1		(0.8)

RINs commitment contracts (2)	Other current assets	2.1		—		9.7		—
RINs commitment contracts (2)	Other current liabilities	—		(3.3)		—		(6.6)
Total gross fair value of derivatives		139.1		(150.9)		328.9		(341.3)
Less: Counterparty netting and cash collateral (3)		124.8		(146.6)		306.2		(320.0)
Total net fair value of derivatives		$	14.3	$	(4.3)	$	22.7	$	(21.3)

(1)As of ~~June~~September 30, 2023 and December 31, 2022, we had open derivative positions representing ~~152,606,574~~86,907,586 and 158,307,020 barrels, respectively, of crude oil and refined petroleum products. Additionally, as of ~~June~~September 30, 2023 and December 31, 2022, we had open derivative positions representing ~~6,787,500~~1,705,000 and 2,310,000 million British Thermal Units ("MMBTU"), respectively, of natural gas products.

(2)As of ~~June~~September 30, 2023 and December 31, 2022, we had open RINs commitment contracts representing ~~81,100,000~~17,000,000 and 259,022,967 RINs, respectively.

(3)As of ~~June~~September 30, 2023 and December 31, 2022, ~~$12.9~~$21.8 million and $13.8 million, respectively, of cash collateral held by counterparties has been netted with the derivatives with each counterparty.

Total gains (losses) on our non-trading commodity derivatives and RINs commitment contracts recorded in the condensed consolidated statements of income are as follows (in millions) (2):


		Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022				2023		2022		2023		2022
Gains (losses) on hedging derivatives not designated as hedging instruments recognized in cost of materials and other (1)	Gains (losses) on hedging derivatives not designated as hedging instruments recognized in cost of materials and other (1)	$	5.3	$	(34.4)	$	10.7	$	(105.8)		Gains (losses) on hedging derivatives not designated as hedging instruments recognized in cost of materials and other (1)	$	(97.1)	$	78.0	$	(86.4)	$	(27.7)
Gains (losses) on non-trading physical forward contract commodity derivatives in cost of materials and other	Gains (losses) on non-trading physical forward contract commodity derivatives in cost of materials and other	—		8.2		(2.4)		4.8			Gains (losses) on non-trading physical forward contract commodity derivatives in cost of materials and other	—		0.3		(2.4)		5.1
Losses on hedging derivatives not designated as hedging instruments recognized in operating expenses	Losses on hedging derivatives not designated as hedging instruments recognized in operating expenses	—		(1.7)		—		(1.7)			Losses on hedging derivatives not designated as hedging instruments recognized in operating expenses	—		—		—		(1.7)

Total gains (losses)	Total gains (losses)	$	5.3	(27.9)		$	8.3	$	(102.7)		Total gains (losses)	$	(97.1)	78.3		$	(88.8)	$	(24.3)

(1) Gains (losses) on commodity derivatives that are economic hedges but not designated as hedging instruments include unrealized gains (losses) of ~~$(6.6)~~$(78.8) million and ~~$23.3~~$(55.5) million for the three and ~~six~~nine months ended ~~June~~September 30, 2023 , respectively, and ~~$66.1~~$24.8 million and ~~$(4.6)~~$20.2 million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.

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


~~21 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

Total gains (losses) on our trading 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 June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022				2023		2022		2023		2022

Trading Physical Forward Contract Commodity Derivatives	Trading Physical Forward Contract Commodity Derivatives										Trading Physical Forward Contract Commodity Derivatives
Realized gains		$	5.9	$	2.9	$	7.2	$	20.9
Realized (losses) gains											Realized (losses) gains	$	0.8	$	1.2	$	8.0	$	19.7
Unrealized gains (losses)	Unrealized gains (losses)	1.9		0.1		0.1		(0.3)			Unrealized gains (losses)	—		—		0.1		(0.3)
Total	Total	$	7.8	$	3.0	$	7.3	$	20.6		Total	$	0.8	$	1.2	$	8.1	$	19.4

Trading Hedging Commodity Derivatives	Trading Hedging Commodity Derivatives										Trading Hedging Commodity Derivatives
Realized (loses) gains		$	(3.1)	$	(3.0)	$	(1.7)	$	11.9
Realized (losses) gains											Realized (losses) gains	$	(0.4)	$	(0.3)	$	(2.1)	$	11.6
Unrealized gains (losses)	Unrealized gains (losses)	1.2		0.6		2.3		(16.5)			Unrealized gains (losses)	0.2		0.7		2.5		(15.8)
Total	Total	$	(1.9)	$	(2.4)	$	0.6	$	(4.6)		Total	$	(0.2)	$	0.4	$	0.4	$	(4.2)


22 \|

Notes to Condensed Financial Statements (Unaudited)

11. Fair Value Measurements

Our assets and liabilities that are measured at fair value include commodity derivatives, investment commodities, environmental credits obligations, our Inventory Intermediation Agreement, and Supply and Offtake Agreements. ASC 820, Fair Value Measurements ("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.

Our commodity derivative contracts, which consist of commodity swaps, exchange-traded futures, options and physical commodity forward purchase and sale contracts (that do not qualify for the NPNS exception under ASC 815), are valued based on exchange pricing and/or price index developers such as Platts or Argus and are, therefore, classified as Level 2.

To the extent that we have purchased RINs or transferred RINs to our refineries, each refinery’s RINs Obligation may be a surplus or deficit at the end of each reporting period (their respective “Net RINs Obligation”). Because our Net RINs Obligations exceed the RINs we are able to generate annually on a consolidated basis, and because we have the legal ability to transfer RINs generated or purchased through any of our entities to our obligated parties as needed, we view and manage the Company’s individual Net RINs Obligations, as well as any non-obligated party RINs holdings, on a consolidated basis. Therefore, the sum of our individual obligated parties’ Net RINs Obligations as well as RINs held by our non-obligated parties which meet our recognition criteria, comprises the Company’s “Consolidated Net RINs Obligation.” Our RINs 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 Consolidated Net RINs Obligation. These RINs commitment contracts (which are forward contracts accounted for as derivatives – see Note 10) are categorized as Level 2, and are measured at fair value based on quoted prices from an independent pricing service.

Our environmental credits obligation surplus or deficit includes the Consolidated Net RINs Obligation surplus or deficit, as well as other environmental credit obligation surplus or deficit positions subject to fair value accounting pursuant to our accounting policy. The environmental credits obligation surplus or deficit is categorized as Level 2, if measured at fair value either directly through observable inputs or indirectly through market-corroborated inputs, and gains (losses) related to changes in fair value are recorded as a component of cost of materials and other in the consolidated statements of income. With respect to our Consolidated Net RINs Obligation surplus or deficit, we recognized gains (losses) on changes in fair value totaling ~~$(2.1)~~$3.6 million and ~~$(1.8)~~$1.8 million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$(39.8)~~$(12.6) million and ~~$(41.0)~~$(53.6) million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively, primarily attributable to changes in the market prices of the underlying credits that occurred at the end of each quarter.


~~22 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

As of and for the three and ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, we elected to account for our Inventory Intermediation step-out liability and 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. With respect to the Inventory Intermediation Agreement and the amended and restated Supply and Offtake Agreements, we apply fair value measurement as follows: (1) we determine fair value for our amended variable step-out liability based on changes in fair value related to market volatility based on a floating commodity-index price, and for our amended fixed step-out liability based on changes to interest rates and the timing and amount of expected future cash settlements where such obligation is categorized as Level 2. Gains (losses) related to changes in fair value due to commodity-index price are recorded as a component of cost of materials and other, and changes in fair value due to interest rate risk are recorded as a component of interest expense in the condensed consolidated statements of income; and (2) we determine fair value of the commodity-indexed revolving over/short inventory financing liability based on the market prices for the consigned crude oil and refined products collateralizing the financing/funding where such obligation is categorized as Level 2 and is presented in the current portion of the Obligation under Inventory Intermediation Agreement on 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 consolidated statements of income. See Note 8 for discussion of gains and losses recognized from changes in fair value.

The fair value of the Delek Logistics 2028 Notes is measured based on quoted market prices in an active market, defined as Level 1 in the fair value hierarchy. The carrying value (excluding unamortized debt issuance costs) and estimated fair value of these notes was $400.0 million and ~~$372.1~~$365.5 million, respectively, as of ~~June~~September 30, 2023, and $400.0 million and $359.7 million, respectively, at December 31, 2022.


23 \|

Notes to Condensed Financial Statements (Unaudited)

The fair value approximates the historical or amortized cost basis comprising our carrying value for all other financial instruments and therefore are not included in the table below. The fair value hierarchy for our financial assets and liabilities accounted for at fair value on a recurring basis was as follows (in millions):


		As of June 30, 2023									As of September 30, 2023
		Level 1		Level 2		Level 3		Total			Level 1		Level 2		Level 3		Total
Assets	Assets									Assets
Commodity derivatives	Commodity derivatives	$	—	$	182.8	$	—	$	182.8	Commodity derivatives	$	—	$	137.0	$	—	$	137.0

RINs commitment contracts	RINs commitment contracts	—		3.0		—		3.0		RINs commitment contracts	—		2.1		—		2.1

Total assets	Total assets	—		185.8		—		185.8		Total assets	—		139.1		—		139.1
Liabilities	Liabilities									Liabilities

Commodity derivatives	Commodity derivatives	—		(174.0)		—		(174.0)		Commodity derivatives	—		(147.6)		—		(147.6)
RINs commitment contracts	RINs commitment contracts	—		(3.9)		—		(3.9)		RINs commitment contracts	—		(3.3)		—		(3.3)
Environmental credits obligation deficit	Environmental credits obligation deficit	—		(76.2)		—		(76.2)		Environmental credits obligation deficit	—		(38.8)		—		(38.8)
Inventory Intermediation Agreement obligation	Inventory Intermediation Agreement obligation	—		(453.4)		—		(453.4)		Inventory Intermediation Agreement obligation	—		(502.2)		—		(502.2)
Total liabilities	Total liabilities	—		(707.5)		—		(707.5)		Total liabilities	—		(691.9)		—		(691.9)
Net liabilities	Net liabilities	$	—	$	(521.7)	$	—	$	(521.7)	Net liabilities	$	—	$	(552.8)	$	—	$	(552.8)


	As of December 31, 2022
	Level 1		Level 2		Level 3		Total
Assets
Commodity derivatives	$	—	$	319.2	$	—	$	319.2

RINs commitment contracts	—		9.7		—		9.7

Total assets	—		328.9		—		328.9
Liabilities
Commodity derivatives	—		(334.7)		—		(334.7)

RINs commitment contracts	—		(6.6)		—		(6.6)
Environmental credits obligation deficit	—		(295.5)		—		(295.5)
Inventory Intermediation Agreement obligation	—		(541.7)		—		(541.7)
Total liabilities	—		(1,178.5)		—		(1,178.5)
Net liabilities	$	—	$	(849.6)	$	—	$	(849.6)

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 ~~June~~September 30, 2023 and December 31, 2022, ~~$12.9~~$21.8 million and $13.8 million, respectively, of cash ~~(obligation)~~ collateral was held by counterparty brokerage firms and has been netted with the net derivative positions with each counterparty. See Note 10 for further information regarding derivative instruments.


~~23 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

Non-Recurring Fair Value Measurements

The Delaware Gathering Acquisition was accounted for as a business combination using the acquisition method of accounting, with the assets acquired and liabilities assumed at their respective acquisition date fair values at the closing date. The fair value measurements were based on a combination of valuation methods including discounted cash flows, the market approach and obsolescence adjusted replacement costs, all of which are Level 3 inputs.

12. 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 this note.


24 \|

Notes to Condensed Financial Statements (Unaudited)

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~~U.S. Department of Transportation and 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.

As of ~~June~~September 30, 2023, we have recorded an environmental liability of approximately $114.7 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 for known contamination of soil and groundwater. Approximately $3.1 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.

Included in our environmental liabilities as of both ~~June~~September 30, 2023 and December 31, 2022 is a liability totaling $78.5 million related to a property that we have historically operated as an asphalt and marine fuel terminal both as an owner and, subsequently, as a lessee under an in-substance lease agreement (the “License Agreement”). The License Agreement, which provided us the license to continue operating our asphalt and marine fuel terminal operations on the property for a term of ten years and expired in June 2020, also ascribed a contractual noncontingent indemnification guarantee to certain of our wholly-owned subsidiaries related to certain incremental environmental remediation activities, predicated on the completion of certain property development activities ascribed to the lessor. Our combined liability, comprised of our environmental liability plus the estimated fair value of the noncontingent guarantee liability, was recorded in connection with the Delek/Alon Merger, effective July 1, 2017. While the License Agreement expired in June 2020, it is currently being disputed in litigation where we have determined that no loss accrual is necessary and that the amount of incremental loss that is reasonably possible is immaterial as of ~~June~~September 30, 2023. Such ongoing dispute causes sufficient uncertainty around the release of risk and the appropriate joint and several liability allocations thereunder that we cannot currently determine a more reasonable estimate of the potential total contingent liability that is probable, nor do we have sufficient information to better estimate the fair value of any remaining noncontingent guarantee liability. As such, as of ~~June~~September 30, 2023 and December 31, 2022, except for accretion and expenditures, our combined environmental liability related to the terminal and property remained unchanged.


~~24 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~

We are also subject to various regulatory requirements related to carbon emissions and the compliance requirements to remit environmental credit obligations due to the EPA or other regulatory agencies, the most significant of which relates to the RINs Obligation subject to the EPA’s ~~RFS-2~~Renewable Fuel Standard - 2 ("RFS-2") regulations. The RFS-2 regulations are highly complex and evolving, requiring us to periodically update our compliance systems. As part of our on-going monitoring and compliance efforts, on an annual basis we engage a third party to perform procedures to review our RINs inventory, processes and compliance. The results of such procedures may include procedural findings but may also include findings regarding the usage of RINs to meet past obligations, the treatment of exported RINs, and the propriety of RINs on-hand and related adjustments to our RINs inventory, which (to the extent they are valued) offset our RINs Obligation. Such adjustments may also require communication with the EPA if they involve reportable non-compliance which could lead to the assessment of penalties.

Other Losses and Contingencies

Delek maintains property damage insurance policies which have varying deductibles. Delek also maintains business interruption insurance policies, with varying coverage limits and waiting periods. Covered losses in excess of the deductible and outside of the waiting period will be recoverable under the property and business interruption insurance policies.


25 \|

Notes to Condensed Financial Statements (Unaudited)

El Dorado Refinery Fire

On February 27, 2021, our El Dorado refinery experienced a fire in its Penex unit. Contrary to initial assessments, and despite occurring during the early stages of turnaround activity, the facility suffered operational disruptions as a result of the fire. We recognized a gain of ~~$0.9~~$0.2 million and ~~$0.9~~$1.1 million during the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and a gain of ~~$3.3~~$0.5 million and ~~$7.6~~$8.1 million during the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively, related to business interruption claims. This gain is included in other operating income in the condensed consolidated statements of income. Additionally, during the three and nine months ended September 30, 2023, we accrued an additional $8.0 million for uncovered litigation, claims and assessments associated with the fire, which are included in operating expenses in the condensed consolidated statements of income. In October 2023, we entered into a settlement agreement with six employees who were injured in the fire. Net impact to us after considering insurance coverage is approximately $10.0 million. If applicable, we accrue receivables for probable insurance or other third-party recoveries. Work to determine the full extent of covered business interruption and property and casualty losses and potential insurance claims is ongoing and may result in the future recognition of insurance recoveries.

Big Spring Refinery Fire

On November 29, 2022, our Big Spring refinery experienced a fire in its diesel hydrotreater unit. The facility suffered operational disruptions as a result of the fire. Accelerated depreciation due to property damaged in the fire was immaterial. We incurred repair costs that may be recoverable under property and casualty insurance policies and we submitted a claim in 2023. We recognized accelerated depreciation in 2022 due to property damaged in the fire, which was recovered during the three and nine months ended September 30, 2023. An additional $3.3 million was recognized as a gain, in excess of these losses, during the three and nine months ended September 30, 2023. This gain is included in other operating income in the condensed consolidated statements of income. If applicable, we accrue receivables for probable insurance or other third-party recoveries. Work to determine the full extent of covered property losses and potential insurance claims is ongoing and may result in the future recognition of insurance recoveries.

Winter Storm Uri

During February 2021, the Company experienced a severe weather event ("Winter Storm Uri") which temporarily impacted operations at all of our refineries. Due to the extreme freezing conditions, we experienced reduced throughputs at our refineries as there was a disruption in the crude supply, as well as damages to various units at our refineries requiring additional operating and capital expenditures. In addition, we recognized no gain and a gain of ~~$3.8 million and~~ $8.9 million during the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and a gain of ~~$5.3~~$6.9 million and ~~$11.0~~$17.9 million during the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively, related to property and business interruption claims. If applicable, we accrue receivables for probable insurance or other third-party recoveries. Work to determine the full extent of covered business interruption and property and casualty losses and potential insurance claims is ongoing and is expected to result in additional future recognition of insurance recoveries.

13. Income Taxes

Under ASC 740, Income Taxes (“ASC 740”) we used an estimated annual tax rate to record income taxes for the three and ~~six~~nine months ended ~~June~~September 30, 2023 and ~~June~~September 30, 2022. Our effective tax rate was ~~71.7%~~18.8% and ~~14.5%~~17.4% for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~21.4%~~19.2% and ~~21.3%~~21.2% for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively. The difference between the effective tax rate and the statutory rate is generally attributable to permanent differences and discrete items. The change in our effective tax rate for the three and ~~six~~nine months ended ~~June~~September 30, 2023 as compared to the three and ~~six~~nine months ended ~~June~~September 30, 2022 was primarily due to a ~~decrease~~change in pre-tax earnings and the impact fixed dollar favorable permanent differences on the tax rate, and ~~changes in~~adjustments to the ~~second~~third quarter estimated annual effective tax rate applied to year to date earnings.

14. Related Party Transactions

Our related party transactions consist primarily of transactions with our equity method investees (See Note 6). Transactions with our related parties were as follows for the periods presented (in millions):

Three Months Ended June 30, Six Months Ended June 30,
2023 2022 2023 2022
Revenues (1)
$ 32.0 $ 27.2 $ 49.9 $ 43.9
Cost of materials and other (2)
$ 52.8 $ 23.7 $ 98.2 $ 47.1


~~25 \|~~

~~Notes to Condensed Financial Statements (Unaudited)~~


	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Revenues (1)	$	35.8	$	37.8	$	85.7	$	81.7
Cost of materials and other (2)	$	54.3	$	34.7	$	152.4	$	81.8

(1)Consists primarily of asphalt sales which are recorded in corporate, other and eliminations segment.

(2)Consists primarily of pipeline throughput fees paid by the refining segment and asphalt purchases.


26 \|

Notes to Condensed Financial Statements (Unaudited)

15. Other Current Assets and Liabilities

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


Other Current Assets	Other Current Assets	June 30, 2023		December 31, 2022		Other Current Assets	September 30, 2023		December 31, 2022
Prepaid expenses	Prepaid expenses	$	49.2	$	45.4	Prepaid expenses	$	42.5	$	45.4
Short-term derivative assets (see Note 10)	Short-term derivative assets (see Note 10)	25.9		22.4		Short-term derivative assets (see Note 10)	14.2		22.4
Investment commodities						Investment commodities	11.5		29.8
Income and other tax receivables	Income and other tax receivables	9.7		20.9		Income and other tax receivables	9.9		20.9
Investment commodities		5.6		29.8

Other	Other	4.2		4.2		Other	7.5		4.2
Total	Total	$	94.6	$	122.7	Total	$	85.6	$	122.7

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


Accrued Expenses and Other Current Liabilities	Accrued Expenses and Other Current Liabilities	June 30, 2023		December 31, 2022		Accrued Expenses and Other Current Liabilities	September 30, 2023		December 31, 2022
Product financing agreements	Product financing agreements	$	322.4	$	258.0	Product financing agreements	$	260.8	$	258.0
El Dorado refinery fire settlement (1)						El Dorado refinery fire settlement (1)	177.5		2.0
Crude purchase liabilities	Crude purchase liabilities	163.7		268.7		Crude purchase liabilities	146.9		268.7
Income and other taxes payable	Income and other taxes payable	132.5		120.4		Income and other taxes payable	145.2		120.4
Employee costs						Employee costs	57.1		89.2
Consolidated Net RINs Obligation deficit (see Note 11)	Consolidated Net RINs Obligation deficit (see Note 11)	76.2		295.5		Consolidated Net RINs Obligation deficit (see Note 11)	38.8		295.5
Employee costs		51.3		91.2
Deferred revenue	Deferred revenue	20.0		44.6		Deferred revenue	13.8		44.6
Short-term derivative liabilities (see Note 10)	Short-term derivative liabilities (see Note 10)	5.4		21.3		Short-term derivative liabilities (see Note 10)	4.2		21.3
Other	Other	53.3		67.1		Other	72.2		67.1
Total	Total	$	824.8	$	1,166.8	Total	$	916.5	$	1,166.8

(1) Refer to Note 12 - Commitments and Contingencies for further information.

16. Equity-Based Compensation

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

On May 3, 2023, 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 2,015,000 shares to 17,010,000 shares. Compensation expense related to equity-based awards granted under the Incentive Plans amounted to ~~$4.9~~$7.2 million and ~~$10.8~~$18.0 million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$6.7~~$7.3 million and ~~$11.8~~$19.1 million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively. These amounts are included in general and administrative expenses and operating expenses in the accompanying condensed consolidated statements of income. As of ~~June~~September 30, 2023, there was ~~$55.3~~$47.5 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 ~~1.7~~1.6 years.

We issued net shares of common stock of ~~308,196~~48,154 and ~~361,839~~409,993 as a result of exercised or vested equity-based awards during the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~289,971~~53,522 and ~~335,771~~389,293 for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively. These amounts are net of ~~125,645~~59,836 and ~~146,108~~205,944 shares withheld to satisfy employee tax obligations related to the exercises and vesting during the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~250,334~~50,521 and ~~268,163~~318,684 shares during the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.


2627 \|

Notes to Condensed Financial Statements (Unaudited)

17. Shareholders' Equity

Dividends

For 2023, our Board of Directors declared the following dividends:

Approval Date

Dividend Amount Per Share

Record Date

Payment Date

February 27, 2023

$0.220

March 10, 2023

March 17, 2023

May 2, 2023

$0.230

May 15, 2023

May 22, 2023

August 4, 2023

$0.235

August 14, 2023

August 21, 2023

November 1, 2023

$0.240

November 13, 2023

November 20, 2023

Stock Repurchase Program

Our Board of Directors has authorized a share repurchase program under which repurchases of Delek common stock may be executed through open market transactions or privately negotiated transactions, in accordance with applicable securities laws. The timing, price and size of repurchases are made at the discretion of management and will depend on prevailing share prices, general economic and market conditions and other considerations. The authorization has no expiration date. During the three and ~~six~~nine months ended ~~June~~September 30, 2023, ~~1,795,335~~981,690 and ~~1,811,627~~2,793,317 shares of our common stock were repurchased and cancelled at the time of transaction for a total of ~~$40.0~~$25.0 million and ~~$40.4~~$65.4 million, respectively. ~~No repurchases were made during~~During both the three and ~~six~~nine months ended ~~June~~September 30, ~~2022.~~2022, 1,435,602 shares were repurchased and cancelled at the time of the transaction for a total of $40.0 million. As of ~~June~~September 30, 2023, there was ~~$230.1~~$205.1 million of authorization remaining under Delek's aggregate stock repurchase program.

Stock Purchase and Cooperation Agreement

On March 7, 2022, Delek entered into a stock purchase and cooperation agreement (the “Icahn Group Agreement”) with IEP Energy Holding LLC, a Delaware limited liability company, American Entertainment Properties Corp., a Delaware corporation, Icahn Enterprises Holdings L.P., a Delaware limited partnership, Icahn Enterprises G.P. Inc., a Delaware corporation, Beckton Corp., a Delaware corporation, and Carl C. Icahn (collectively, the “Icahn Group”), pursuant to which the Company purchased an aggregate of 3,497,268 shares of Company common stock from the Icahn Group at a price per share of $18.30, the closing price of a share of Company common stock on the NYSE on March 4, 2022. The aggregate purchase price of $64.0 million was funded from cash on hand. All 3,497,268 shares were cancelled at the time of the transaction.

Under the terms of the Icahn Group Agreement, the Icahn Group withdrew its notice of nomination for members of the Company’s board of directors at the Company’s 2022 annual meeting of stockholders. Under the terms of the Icahn Group Agreement, the Icahn Group agreed to standstill restrictions which require, among other things, that until the completion of the Company’s 2023 annual meeting of stockholders, the Icahn Group will refrain from acquiring additional shares of the Company Common Stock.

18. Subsequent Events

Stock Repurchases

Subsequent to ~~June~~September 30, 2023, we made repurchases of ~~981,690~~769,450 shares of our common stock that were cancelled at the time of transaction for approximately ~~$25.0~~$20.0 million.


2728 \|

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, 2023 (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.

Delek US Holdings, Inc. is a registrant pursuant to the Securities Act of 1933, as amended ("Securities Act") and is listed on the New York Stock Exchange ("NYSE") under the ticker symbol "DK". 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 Delek US Holdings, Inc. and its consolidated subsidiaries for all periods presented. 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.

The Company announces material information to the public about the Company, its products and services and other matters through a variety of means, including filings with the SEC, press releases, public conference calls, the Company’s website (www.delekus.com), the investor relations section of its website (ir.delekus.com), the news section of its website (www.delekus.com/news), and/or social media, including its Twitter account (@DelekUSHoldings). The Company encourages investors and others to review the information it makes public in these locations, as such information could be deemed to be material information. Please note that this list may be updated from time to time.

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 ("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, statements that refer to the acquisition of 3 Bear Delaware Holding – NM, LLC ("3 Bear") (subsequently renamed to Delek Delaware Gathering ("Delaware Gathering")) (the "Delaware Gathering Acquisition"), including any statements regarding the expected benefits, synergies, growth opportunities, impact on liquidity and prospects, and other financial and operating benefits thereof, the information concerning possible future results of operations, business and growth strategies, including as the same may be impacted by any ongoing military conflict, such as the war between Russia and Ukraine ("the Russia-Ukraine War"), 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;

•reliability of our operating assets;

•actions of our competitors and customers;

•changes in, or the failure to comply with, the extensive government regulations applicable to our industry segments, including current and future restrictions on commercial and economic activities in response to future public health crises;

•our ability to execute our long-term sustainability strategy and growth through acquisitions such as the Delaware Gathering Acquisition and joint ventures, including our ability to successfully integrate acquisitions, complete strategic transactions, safety initiatives and capital projects, realize expected synergies, cost savings and other benefits therefrom, return value to shareholders, or achieve operational efficiencies;

•diminishment 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;

•the impact on commercial activity and other economic effects of any widespread public health crisis, including uncertainty regarding the timing, pace and extent of economic recovery following any such crisis;

•general economic and business conditions affecting the southern, southwestern and western U.S., 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);

•unanticipated increases in cost or scope of, or significant delays in the completion of, our capital improvement safety initiative 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, weather related disruptions, casualty losses and other matters beyond our control;

•increases in our debt levels or costs;

•possibility of accelerated repayment on a portion of our Inventory Intermediation Obligation if the purchase price adjustment feature triggers a change on the re-pricing dates;

•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;

•changes in our ability to pay dividends;

•seasonality;

•earthquakes, hurricanes, tornadoes, and other weather events, which can unforeseeably affect the price or availability of electricity, natural gas, crude


2829 \|

Management's Discussion and Analysis

oil, and other feedstocks, critical supplies, refined petroleum products and ethanol;

•increases in costs of compliance with, or liability for violation of, existing or future laws, regulations and other requirements;

•societal, legislative and regulatory measures to address climate change and greenhouse gases ~~emissions;~~emissions ("GHG");

•our ability to execute our sustainability improvement plans, including greenhouse gas reduction targets;

•acts of terrorism (including cyber-terrorism) aimed at either our facilities or other facilities;

•impacts of global conflicts such as the war between Israel and Hamas (the "Israel-Hamas War") and the Russia-Ukraine War;

•future decisions by the Organization of Petroleum Exporting Countries ("OPEC") and the members of other leading oil producing countries

~~(together~~ (together with OPEC, “OPEC+”) regarding production and pricing and disputes between OPEC+ members regarding the same;

•disruption, failure, or cybersecurity breaches affecting or targeting our IT systems and controls, our infrastructure, or the infrastructure of our cloud-based IT service providers;

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

•other factors discussed under Item 1A. Risk Factors and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations 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. All forward-looking statements included in this report are based on information available to us on the date of this report. We undertake no obligation to revise or update any forward-looking statements as a result of new information, future events or otherwise.


2930 \|

Management's Discussion and Analysis

Executive Summary: Management's View of Our Business and Strategic Overview


Management's View of Our Business

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. Our operating segments consist of refining, logistics, and retail, and are discussed in the sections that follow.

During the fourth quarter 2022, we realigned our reportable segments for financial reporting purposes to reflect changes in the manner in which our chief operating decision maker, or CODM, assesses financial information for decision-making purposes. The change primarily represents reporting the operating results of wholesale crude operations within the refining segment. Prior to this change, wholesale crude operations were reported as part of corporate, other and eliminations. In addition, during the fourth quarter 2022, the CODM determined that EBITDA is the key performance measure for planning and forecasting purposes and discontinued the use of contribution margin as a measure of performance. We define EBITDA for any period as net income (loss) to add back interest expense, income tax expense (benefit), depreciation and amortization. While these reporting changes did not change our consolidated results, segment data for previous years has been restated and is consistent with the current year presentation throughout the financial statements and the accompanying notes.

Business and Economic Environment Overview

Our focus on safe and reliable operations is a pillar which underlines all of our business activities. We continue to identify opportunities to mitigate market risk and focus on efforts that improve our overall cost structure while not compromising operational excellence. Although average crack spreads were lower than the ~~historic highs in the second~~third quarter of 2022, refining margins remain strong and demand for refined products has been robust despite a rise in crude oil prices driven by the continued constrained supply in the markets we serve. During the ~~second~~third quarter 2023, given the strong refining margins, we ~~experienced reduced throughputs at~~made a strategic decision to optimize our ~~refineries as~~inventory levels to reduce carrying costs and improve working capital efficiency. As a result of ~~unplanned downtime including a catalyst change at~~the decreased inventory levels, we had to rebalance our ~~Big Spring refinery requiring additional operating and capital expenditures and weather related~~hedging positions which resulted in realizing hedging positions that were in loss positions due to the increased price environment. We will continue to identify opportunities for operational disruptions at our El Dorado refinery, partially offset by improved throughputs at our Tyler refinery as a result of turnaround activities completed in the first quarter 2023. The favorable domestic crack spreads and increased U.S. export demand has encouraged expansion in domestic refining capacity.efficiency improvements. The domestic ~~WTI~~West Texas Intermediate ("WTI") differentials compared to Brent continued to be favorable during the ~~second~~third quarter of 2023, while the WTI Midland differential to Cushing ~~remained relatively flat coming off~~premium increased compared to the ~~first~~second quarter 2023. Further impacting the favorability of our current quarter results were record refinery throughput rates driven by safe and reliable operations. Additionally, our logistics segment contributed strong results and our integration of Delek Delaware Gathering (formally 3 Bear) has expanded our existing crude oil gathering throughput capacity in the Permian while also extending our product offering to include natural gas gathering and processing as well as wastewater recycling and disposal. Our retail operations have benefited from seasonal demand from U.S. drivers and present several high-growth opportunities to capitalize on growing consumer demand for ~~future investment~~convenient and accessible fueling options which will complement our existing operations and build brand equity. In September 2023, we opened a new-to-industry retail location in Tyler, TX. Our first store in this market, which features expanded food service and leading digital technology.

~~Although the~~The near term economic outlook ~~appears favorable,~~is uncertain, and as a result we ~~are positioning~~continue to position the Company for potential economic headwinds that coincide with a potential global downturn in the economy. We continue to progress our business transformation focused on enterprise-wide opportunities to improve the efficiency of our cost structure. The expectation of reduction in the reliance of liquid fuels, a tightening of capital markets, increased regulatory pressures, and volatility in the commodity markets, are considerations that Delek must balance as we move forward with our strategic initiatives.

The energy-related legislation passed with the Inflation Reduction Act ("IRA") encompasses clean energy financial incentives that are expected to increase capital investment opportunities that focus on the development of production capacity for liquid fuels with lower ~~greenhouse gas emissions ("GHG").~~GHG. Gulf coast industries should be well positioned for growth, particularly if global trade becomes tied to environmental attributes. Our focus on reduction of ~~greenhouse gas emissions~~GHG is a key objective as we strive to be a leader in the transition to a carbon neutral future. Delek formed the Sustainable Operations Team ("SOT") in 2022 which is led by our ~~EVP,~~Executive Vice President, Operations. The SOT will coordinate execution of our sustainability improvement plans (beginning with GHG reduction targets) ensuring enterprise strategies, business unit operations, capital spending plans, supply chain and personnel pipeline are in alignment and operating as needed to meet established goals. Delek prioritizes stewardship of the environment, and we focus on how to positively impact our shareholders, employees, customers, and the communities where we operate.

Our near-term focus is centered around safe and reliable operations, shareholder returns including debt reductions and unlocking the "sum of the parts" value of our existing business while identifying growth opportunities to enhance the Company's scale and diversify revenue streams, including in the alternative energy markets and creating a long-term sustainable business model. We believe these strategic priorities will maximize the value of our shareholders while optimizing our asset portfolio and balance sheet.

See further discussion on macroeconomic factors and market trends, including the impact on 2023 and the outlook for the rest of the year, in the ‘Market Trends’ section below.


3031 \|

Management's Discussion and Analysis


Refining Overview

The refining segment (or "Refining") processes crude oil and other 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. The refining segment has a combined nameplate capacity of 302,000 ~~bpd~~barrels per day ("bpd") as of ~~June~~September 30, 2023. A high-level summary of the refinery activities is presented below:

Tyler, Texas refinery
(the "Tyler refinery")

El Dorado, Arkansas refinery
(the "El Dorado refinery")

Big Spring, Texas refinery (the "Big Spring refinery")

Krotz Springs, Louisiana refinery
(the "Krotz Springs refinery")

Total Nameplate Capacity (bpd)

75,000

80,000

73,000

74,000

Primary Products

Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, petroleum coke and sulfur

Gasoline, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, asphalt and sulfur

Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, aromatics and sulfur

Gasoline, jet fuel, high-sulfur diesel, light cycle oil, liquefied petroleum gases, propylene and ammonium thiosulfate

Relevant Crack Spread Benchmark

Gulf Coast 5-3-2

Gulf Coast 5-3-2 (1)

Gulf Coast 3-2-1 (2)

Gulf Coast 2-1-1 (3)

Marketing and Distribution

The refining segment's petroleum-based products are marketed primarily in the south central and southwestern regions of the United States, and the refining segment also ships and sells gasoline into wholesale markets in the southern and eastern United States. Motor fuels are sold under the Alon or Delek brand through various terminals to supply Alon or Delek branded retail sites. In addition, we sell motor fuels through our wholesale distribution network on an unbranded basis.

(1) While there is variability in the crude slate and the product output at the El Dorado refinery, we compare our per barrel refined product margin to the U.S. Gulf Coast ("Gulf Coast") 5-3-2 crack spread because we believe it to be the most closely aligned benchmark.

(2) 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 oil, and therefore the ~~West Texas Intermediate ("WTI")~~WTI Cushing/ West Texas Sour ("WTS") price differential, taking into account differences in production yield, is an important measure for helping us make strategic, market-respondent production decisions.

(3) The Krotz Springs refinery has the capability to process substantial volumes of light sweet crude oil to produce a high percentage of refined light products.

Our refining segment also owns and operates three biodiesel facilities involved in the production of biodiesel fuels and related activities, located in Crossett, Arkansas, Cleburne, Texas, and New Albany, Mississippi. In addition, the refining segment includes our wholesale crude operations.


Logistics Overview

Our logistics segment (or "Logistics") gathers, transports and stores crude oil and natural gas; markets, distributes, transports and stores refined products; and disposes and recycles water in select regions of the southeastern United States, West Texas and New Mexico for our refining segment and third parties. It is comprised of the consolidated balance sheet and results of operations of Delek Logistics (NYSE: DKL), where we owned a 78.7% interest at ~~June~~September 30, 2023. Delek Logistics 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 currently integral to our refining and marketing operations. The logistics segment's gathering and processing business owns or leases capacity on approximately 400 miles of crude oil transportation pipelines, approximately 450 miles of refined product pipelines, and an approximately 1,120-mile crude oil gathering system. The storage and transportation business owns or leases associated crude oil storage tanks with an aggregate of approximately 10.3 million barrels of active shell capacity. It also owns and operates ten light product terminals and markets light products using third-party terminals. Logistics has strategic investments in pipeline joint ventures that provide access to pipeline capacity as well as the potential for earnings from joint venture operations. The logistics segment owns or leases approximately 264 tractors and 353 trailers used to haul primarily crude oil and other products for related and third parties.


Retail Overview

Our retail segment (or "Retail") at ~~June~~September 30, 2023 includes the operations of ~~247~~250 owned and leased convenience store sites located primarily in West Texas and New Mexico. Our convenience stores typically offer various grades of gasoline and diesel under the DK or 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 DK or Alon brand names pursuant to a license agreement with 7-Eleven, Inc. In November 2018, we terminated the license agreement with 7-Eleven, Inc. and the terms of such termination and subsequent amendments require the removal of all 7-Eleven branding on a store-by-store basis by December 31, 2023. Merchandise at our convenience store sites will continue to be sold under the 7-Eleven brand name until 7-Eleven branding is removed pursuant to the termination. As of ~~June~~September 30, 2023, we have removed the 7-Eleven brand name at ~~145~~180 of our store locations. 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.


Corporate and Other Overview

Our corporate activities, results of certain immaterial operating segments, and intercompany eliminations are reported in 'corporate, other and


32 \|

Management's Discussion and Analysis

eliminations' in our segment disclosures. Additionally, our corporate activities include certain of our commodity and other hedging activities.


~~31 \|~~

~~Management's Discussion and Analysis~~


Strategic Overview

A New Framework: Long-Term Sustainability

The emphasis on environmental responsibility and long-term economic and environmental sustainability is accelerating, with increased demand for transparency evolving out of the Environmental, Social and Governance ("ESG") movement. As we evaluate our current ESG positioning in the market, we also must integrate a broader sustainability view to all of our activities, both operational and strategic. For these reasons, we have developed a Long-Term Sustainability Framework, which will help us to formulate our strategic objectives and initiatives.

Long-Term Sustainability Framework: Overarching Objectives

Certain fundamental principles are foundational to our Long-Term Sustainability Framework, and direct us as we develop our guiding objectives. With that in mind, we have initially identified the following overarching ~~objectives~~:objectives:

I. Redirect Corporate Culture towards Innovation, Excellence, and Operating Discipline.

II. Focus on Operational Optimization and Improved Margin Capture.

III. Implement Digital Transformation Strategy.

IV. Identify ESG-Conscious Investments with Clear Value Propositions and Sustainable Returns.

V. Evaluate Strategic Priorities and Redefine Long-term Sustainable Business Model.


3233 \|

Management's Discussion and Analysis

Long-Term Sustainability Framework: Key Initiatives

Safe and Reliable Operations

We are committed to maintaining safe, reliable, and environmentally responsible operations. We are continuously looking to reduce costs, increase reliability and safety, improve efficiency, and pursue operational improvements. Delek prioritizes stewardship of the environment, and we focus on how to positively impact our shareholders, employees, customers, and the communities where we operate. For 2023, we will be focused on the following:

•Focus on operational excellence by implementing and sustaining a low operating cost model through spending discipline, supply chain management, and innovative solutions.

•Improve discipline around outage spend and optimizing downtimes.

•Continue our progression of digital system implementations that will improve our ability to understand all aspects of our business as well as our ability to make real-time and forward-looking operational decisions. Automate processes and shift operational roles to higher value-added activities.


			Financial Flexibility & Shareholder Returns We believe shareholder value is strengthened through, among other things, a stable dividend complemented by share repurchases and debt reductions. We also want to reward our shareholders with a competitive long-term capital allocation framework. One of our near-term initiatives is centered around unlocking the "sum of the parts" value of our existing business while identifying growth opportunities to enhance the Company's scale and diversify revenue streams, including in the alternative energy markets. We are also committed to lowering costs and improving the efficiency of our cost structure in all aspects of our business and will continue to focus on operational excellence. We are continuously looking to improve our operating and general and administrative cost structure. For 2023, we will be focused on the following: •Explore opportunities to monetize our retail operations or some of our investment in Delek Logistics, which will help us to better capture tangible value in the Delek valuation, while also improving liquidity in the market for DKL units without dilution of overall DKL market capitalization. •Reward our shareholders with a competitive long-term capital allocation framework including share repurchases and an evaluation of debt reductions which will continue to strengthen our balance sheet. •Monitor performance of our first phase of a zero-based budget for 2023 by setting clear mechanisms for tracking costs, including how to address variances and reallocate funds.

Long-Term Sustainable Business Model

It is vitally important that our strategic process, especially in view of the evolutionary direction of our macroeconomic and geopolitical environment, involves a continuous evaluation of our business model in terms of long-term economic and operational sustainability. We are operating in a mature industry, with increasingly difficult operational and regulatory challenges and, likewise, pressure on operating costs/gross margins as well as the availability and cost of capital. More consolidation in our industry is expected as the regulatory environment continues to move towards reducing carbon emissions and transitions to renewable energy in the long-term. Additionally, evolving consumer and capital markets sentiment, regulations, supply chain constraints and customer demand are expected to cause disruption and increasing pressure in the intermediate term. In order to compete under historic environmental and regulatory changes, companies in our industry will need to be adaptive, forward-thinking and strategic in their approach to long-term sustainability. For 2023, we will be focused on the following:

•Continue our retail rebranding efforts and retail growth plans with additional new-to-industry locations in the planning phase. In addition, invest in industry leading digital technology which will improve brand image and customer experience.

•Identify and evaluate investment opportunities that fit our sustainability view and integrate into our current asset footprint, including strategic investments or joint ventures in renewables, incubator investments in new technologies, and other core-business investments that could improve our scalability and agility.

•Deploy integrated solutions to simplify architecture, data management, and cybersecurity.

•Pursuit of strategic investments and acquisitions with a focus on diversifying revenue streams.


3334 \|

Management's Discussion and Analysis


2023 Strategic Developments

The following table highlights our 2023 Strategic Developments:

2023 Key Initiatives

2023 Strategic Developments

Safe & Reliable Operations

Financial Flexibility & Shareholder Returns

Long Term Sustainable Business Model

Improving Discipline Around Outage Spend and Optimizing Downtime:

Successfully completed the Tyler refinery turnaround in the first quarter of 2023 with zero process or safety incidents. The turnaround was completed substantially on time and on budget and positions us to capture market opportunities.

Implementing Phase 1 of Our Zero-Based Budget:

We have taken steps to improve the efficiency of our cost structure and to align with our strategic priorities to drive cost efficiencies, which include cost reductions in general and administrative expenses. We are targeting $100 million run-rate cost reduction in 2024.

Reducing Debt to Provide Shareholder Value:

During the ~~six~~nine months ended ~~June~~September 30, 2023, we reduced our long-term obligations by approximately ~~$246.7~~$422.4 million.

Focus on Leadership:

In March 2023, Joseph Israel was named Executive Vice President, Operations and will be responsible for refining operations at Delek and for logistics operations at Delek Logistics. Mr. Israel has 25 years of energy experience and a proven track record of driving operational excellence. Also in March 2023, Patrick Reilly was appointed Executive Vice President and Chief Commercial Officer. Mr. Reilly will work closely with Delek's management team to lead the Company's strategies to achieve its short and long-term objectives. Mr. Reilly has over 20-years of energy oil refining and trading experience. In April 2023, Tommy Chavez who has over three decades of refining experience was named Senior Vice President, Refining Operations. ~~Mr. Chavez brings over three decades of refining experience.~~

Improving Safety Through a Safety Action Plan:

As part of an ongoing review of safety practices across our refining system, we have developed a Safety Action Plan which will require previously un-budgeted capital expenditures and additional labor resources and subject matter experts. The execution of the Safety Action Plan will address a broad range of items, some of which were delayed in implementation due to the pandemic, or for other reasons.

Increasing Shareholder Value through Payment of Dividends:

We ~~maintained~~increased our quarterly cash dividend ~~including the quarterly cash dividend of $0.235~~to $0.240 per share of our common stock which was declared by our Board of Directors on ~~August 4,~~November 1, 2023 and payable on ~~August 21,~~November 20, 2023. In addition, a cash dividend of ~~$0.23~~$0.230 per share of our common stock was paid on May 22, 2023 and a cash dividend of $0.235 per share of our common stock was paid on August 21, 2023.

Increasing Shareholder Value through Share Repurchases:

During the three and nine months ended ~~months ended June~~September 30, 2023, ~~1,795,335~~981,690 and 2,793,317 shares of our common stock were repurchased for a total of ~~$40.0~~$25.0 million. and $65.4 million, respectively. Subsequent to ~~June~~September 30, 2023, ~~981,690~~769,450 shares of our common stock were repurchased for a total of ~~$25.0~~$20.0 million.

Executing Retail Growth Plans:

In September 2023, we opened a new-to-industry retail location in Tyler, TX. Our first store in this market, which features expanded food serviced and leading digital technology.

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, among others. Historically, the impact of commodity price volatility on our refining margins (as defined in our "Non-GAAP Measures" in MD&A Item 2.), specifically as it relates to the price of crude oil as compared to the price of refined products and timing differences in the movements of those prices (subject to our inventory costing methodology), as well as location differentials, may be favorable or unfavorable compared to peers. Additionally, our refining margin profitability is impacted by regulatory factors, including the cost of renewable identification numbers ("RINs").

Market Outlook for the Remainder of 2023

We have positioned the Company to continue to run safely, reliably and environmentally responsibly at near or above nameplate capacity while leveraging our new Delek Delaware Gathering lines of business with an eye towards the One Delek vision. Many uncertainties remain with respect to the global supply and demand of the crude oil and refined products markets and it is difficult to predict the ultimate economic impacts this may have on our operations. WeGasoline and diesel demand have returned to pre-pandemic levels and we expect gasoline and diesel demand to continue to follow typical seasonal patterns ~~resulting from~~after the summer driving season. Crude oil and refined product supply continues to be restricted and should support the continued increased utilization of refining capacity which we expect to result in continued strong market conditions in downstream refining.


35 \|

Management's Discussion and Analysis

See below for further discussion on how certain key market trends impact our operating results.


3436 \|

Management's Discussion and Analysis


Crude Prices

WTI crude oil represents the largest component of our crude slate at all of our refineries, and can be sourced through our gathering channels or optimization efforts from Midland, Texas or Cushing, Oklahoma or other locations. We manage our supply chain risk to ensure that we have the barrels to meet our crude slate consumption plan for each month through gathering supply contracts and throughput agreements on various strategic pipelines, some of which include those where we hold equity method investments. We manage market price risk on crude oil through financial derivative hedges, in accordance with our risk management strategies.

The table below reflects the quarterly average prices of WTI Midland and WTI Cushing crude oil for each of the quarterly periods in 2022 and for the ~~two~~three quarterly periods in 2023.


Crude Pricing Differentials

Historically, domestic refiners have benefited from the discount for WTI Cushing compared to Brent, a global benchmark crude. 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. Because of our positioning in the Permian basin, including our access to significant sources of WTI Midland crude through our gathering system, we are even further benefited by discounts for WTI Midland/WTI Cushing differentials. When these discounts shrink or become premiums, our reliance on WTI-linked crude pricing, and specifically WTI Midland crude, can negatively impact our refining margins. Conversely, as these price discounts widen, so does our competitive advantage, created specifically by our access to WTI Midland crude sourced through our gathering systems.

The chart below illustrates the key differentials impacting our refining operations, including WTI Cushing to Brent, WTI Midland to WTI Cushing, and Louisiana Light Sweet crude oil ("LLS") to WTI Cushing for each of the quarterly periods in 2022 and for the ~~two~~three quarterly periods in 2023.


3537 \|

Management's Discussion and Analysis


Refined Product Prices

We are impacted by refined product prices in two ways: (1) in terms of the prices we are able to sell our refined product for in our refining segment, and (2) in terms of the cost to acquire the refined products to meet Refining production shortfalls (e.g., when we have outages), or to acquire refined fuel products we sell to our wholesale customers in our logistics segment and at our convenience stores in our retail segment. These prices largely 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 refineries produce the following products:

Tyler Refinery

El Dorado Refinery

Big Spring Refinery

Krotz Springs Refinery

Primary Products

Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, petroleum coke and sulfur

Gasoline, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, asphalt and sulfur

Gasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, aromatics and sulfur

Gasoline, jet fuel, high-sulfur diesel, light cycle oil, liquefied petroleum gases, propylene and ammonium thiosulfate

The charts below illustrate the quarterly average prices of Gulf Coast Gasoline ("CBOB"), U.S. High Sulfur Diesel ("HSD") and U.S. Ultra Low Sulfur Diesel ("ULSD") for each of the quarterly periods in 2022 and for the ~~two~~three quarterly periods in 2023.


Crack Spreads

Crack spreads are used as benchmarks for predicting and evaluating a refinery's product margins by measuring the difference between the market price of feedstocks/crude oil and the resultant refined products. Generally, a crack spread represents the approximate refining margin resulting from processing one barrel of crude oil into its outputs, generally gasoline and diesel fuel.

The table below reflects the quarterly average Gulf Coast 5-3-2 ULSD, 3-2-1 ULSD and 2-1-1 HSD/LLS crack spreads for each of the quarterly periods in 2022 and for the ~~two~~three quarterly periods in 2023.


3638 \|

Management's Discussion and Analysis


RIN Volatility

Environmental regulations and the political environment continue to affect our refining margins in the form of volatility in the price of RINs. We enter into future commitments to purchase or sell RINs at fixed prices and quantities, which are used to manage the costs of our credits for commitments required by the ~~EPA~~U.S. Environmental Protection Agency (“EPA”) to blend biofuels into fuel products ("RINs Obligation"). On a consolidated basis, we work to balance our RINs Obligation in order to minimize the effect of RINs prices on our results. While we obtain RINs in our refining and logistics segments through our ethanol and biodiesel blending and generate RINs through biodiesel production, our refining segment still must purchase additional RINs to satisfy its obligations. Additionally, our ability to obtain RINs through blending is limited by our refined product slate, blending capabilities and market constraints. The cost to purchase these additional RINs is a significant cash outflow for our business. Increases in the market prices of RINs generally adversely affect our results of operations through changes in fair value to our existing RINs Obligation, to the extent we do not have offsetting RINs inventory on hand or effective economic hedges through net forward purchase commitments. RINs prices are highly sensitive to regulatory and political influence and conditions, and therefore often do not correlate to movements in crude oil prices, refined product prices or crack spreads. Because of the volatility in RINs prices, it is not possible to predict future RINs cost with certainty, and movements in RINs prices can have significant and unanticipated adverse effects on our refining margins that are outside of our control.

The chart below illustrates the volatility in RINs for each of the quarterly periods in 2022 and for the ~~two~~three quarterly periods in 2023.


Energy Costs

Energy costs are a significant element of our Refining EBITDA and can significantly impact our ability to capture crack spreads, with natural gas representing the largest component. Natural gas prices are driven by supply-side factors such as amount of natural gas production, level of natural gas in storage and import and export activity, while demand-side factors include variability of weather, economic growth and the availability and price of other fuels. Refiners and other large-volume fuel consumers may be more or less susceptible to volatility in natural gas prices depending on their consumption levels as well as their capabilities to switch to more economical sources of fuel/energy. Additionally, geographic location of facilities make consumers vulnerable to price differentials of natural gas available at different supply hubs. Within Delek’s geographic footprint, we source the majority of our natural gas from the Gulf Coast, and secondarily from the Permian, coinciding with the physical locations of our refineries. We manage our risk around natural gas prices by entering into variable and fixed-price supply contracts in both the Gulf and Permian Basin or by entering into derivative hedges based on forecasted consumption and forward curve prices, as appropriate, in accordance with our risk policy.

The chart below illustrates the quarterly average prices of Waha (Permian Basin) and Henry Hub (Gulf Coast) per million British Thermal Units ("MMBtu") for each of the quarterly periods in 2022 and for the ~~two~~three quarterly periods in 2023.


3739 \|

Management's Discussion and Analysis

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:

•Earnings before interest, taxes, depreciation and amortization ("EBITDA") - calculated as net income (loss) attributable to Delek adjusted to add back interest expense, income tax expense, depreciation and amortization; and

•Refining margin - calculated as gross margin (which we define as sales minus cost of sales) adjusted for operating expenses and depreciation and amortization included in cost of sales.

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.

Non-GAAP Reconciliations

The following table provides a reconciliation of segment EBITDA to the most directly comparable U.S. GAAP measure, net income attributable to Delek:

Reconciliation of segment EBITDA to net ~~(loss)~~ income attributable to Delek (in millions)


		Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022				2023		2022		2023		2022
Refining segment EBITDA	Refining segment EBITDA	$	110.5	$	587.9	$	302.6	$	667.9		Refining segment EBITDA	$	285.1	$	90.3	$	587.7	$	758.2
Logistics segment EBITDA	Logistics segment EBITDA	90.9		62.6		182.3		126.8			Logistics segment EBITDA	96.5		87.3		278.8		214.1
Retail segment EBITDA	Retail segment EBITDA	15.0		12.5		21.4		22.8			Retail segment EBITDA	16.2		13.5		37.6		36.3
Corporate, Other and Eliminations EBITDA	Corporate, Other and Eliminations EBITDA	(58.7)		(89.2)		(108.6)		(127.3)			Corporate, Other and Eliminations EBITDA	(64.0)		(56.1)		(172.6)		(183.4)
EBITDA attributable to Delek	EBITDA attributable to Delek	$	157.7	$	573.8	$	397.7	$	690.2		EBITDA attributable to Delek	$	333.8	$	135.0	$	731.5	$	825.2
Interest expense, net	Interest expense, net	(80.4)		(43.6)		(156.9)		(82.0)			Interest expense, net	(82.3)		(50.7)		(239.2)		(132.7)
Income tax benefit (expense)		3.8		(100.4)		(12.0)		(103.5)
Income tax expense											Income tax expense	(31.5)		(4.0)		(43.5)		(107.5)
Depreciation and amortization	Depreciation and amortization	(89.4)		(68.0)		(172.8)		(136.3)			Depreciation and amortization	(91.3)		(72.9)		(264.1)		(209.2)
Net (loss) income attributable to Delek		$	(8.3)	$	361.8	$	56.0	$	368.4
Net income attributable to Delek											Net income attributable to Delek	$	128.7	$	7.4	$	184.7	$	375.8

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

Reconciliation of refining margin to gross margin (in millions)


Refining Segment	Refining Segment									Refining Segment
		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022					2023		2022		2023		2022
Total revenues	Total revenues	$	4,052.5	$	5,874.9	$	7,847.0	$	10,267.2			Total revenues	$	4,624.5	$	5,167.4	$	12,471.5	$	15,434.6
Cost of sales	Cost of sales	3,996.9		5,315.8		7,651.4		9,681.5				Cost of sales	4,394.4		5,138.0		12,045.8		14,819.5
Gross margin	Gross margin	$	55.6	$	559.1	$	195.6	$	585.7			Gross margin	$	230.1	$	29.4	$	425.7	$	615.1
Add back (items included in cost of sales):	Add back (items included in cost of sales):											Add back (items included in cost of sales):
Operating expenses (excluding depreciation and amortization)	Operating expenses (excluding depreciation and amortization)	153.8		169.4		292.9		292.1				Operating expenses (excluding depreciation and amortization)	166.5		175.4		459.4		467.5
Depreciation and amortization	Depreciation and amortization	59.8		49.9		116.4		102.7				Depreciation and amortization	60.1		48.9		176.5		151.6
Refining margin	Refining margin	$	269.2	$	778.4	$	604.9	$	980.5			Refining margin	$	456.7	$	253.7	$	1,061.6	$	1,234.2


3840 \|

Management's Discussion and Analysis

Summary Financial and Other Information

The following table provides summary financial data for Delek (in millions):


Summary Statement of Operations Data (1)	Summary Statement of Operations Data (1)	Three Months Ended June 30,				Six Months Ended June 30,				Summary Statement of Operations Data (1)	Three Months Ended September 30,		Nine Months Ended September 30,

		2023		2022 (2)		2023		2022 (2)					2023		2022 (2)		2023		2022 (2)
Net revenues	Net revenues	$	4,195.6	$	5,982.6	$	8,119.9	$	10,441.7			Net revenues	$	4,748.4	$	5,324.9	$	12,868.3	$	15,766.6
Cost of sales:	Cost of sales:											Cost of sales:
Cost of materials and other	Cost of materials and other	3,766.6		5,082.6		7,206.2		9,235.1				Cost of materials and other	4,122.1		4,916.0		11,328.3		14,151.1
Operating expenses (excluding depreciation and amortization presented below)	Operating expenses (excluding depreciation and amortization presented below)	188.7		192.7		359.5		335.1				Operating expenses (excluding depreciation and amortization presented below)	217.7		201.3		577.2		536.4
Depreciation and amortization	Depreciation and amortization	82.6		62.8		159.4		125.5				Depreciation and amortization	83.7		66.5		243.1		192.0
Total cost of sales	Total cost of sales	4,037.9		5,338.1		7,725.1		9,695.7				Total cost of sales	4,423.5		5,183.8		12,148.6		14,879.5

Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below)	Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below)	31.1		34.0		58.1		61.4				Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below)	22.7		28.2		80.8		89.6
General and administrative expenses	General and administrative expenses	75.8		122.3		147.3		172.5				General and administrative expenses	72.0		59.3		219.3		231.8
Depreciation and amortization	Depreciation and amortization	6.8		5.2		13.4		10.8				Depreciation and amortization	7.6		6.4		21.0		17.2

Other operating income, net	Other operating income, net	(6.1)		(10.3)		(16.9)		(38.7)				Other operating income, net	(2.1)		(5.8)		(19.0)		(44.5)
Total operating costs and expenses	Total operating costs and expenses	4,145.5		5,489.3		7,927.0		9,901.7				Total operating costs and expenses	4,523.7		5,271.9		12,450.7		15,173.6
Operating income	Operating income	50.1		493.3		192.9		540.0				Operating income	224.7		53.0		417.6		593.0
Interest expense, net	Interest expense, net	80.4		43.6		156.9		82.0				Interest expense, net	82.3		50.7		239.2		132.7
Income from equity method investments	Income from equity method investments	(25.5)		(15.7)		(40.1)		(26.6)				Income from equity method investments	(27.0)		(17.8)		(67.1)		(44.4)

Other expense (income), net	Other expense (income), net	0.5		(3.6)		(6.6)		(2.3)				Other expense (income), net	1.8		(0.7)		(4.8)		(3.0)
Total non-operating expenses, net	Total non-operating expenses, net	55.4		24.3		110.2		53.1				Total non-operating expenses, net	57.1		32.2		167.3		85.3
(Loss) income before income tax (benefit) expense		(5.3)		469.0		82.7		486.9
Income tax (benefit) expense		(3.8)		100.4		12.0		103.5
Income before income tax expense												Income before income tax expense	167.6		20.8		250.3		507.7
Income tax expense												Income tax expense	31.5		4.0		43.5		107.5

Net (loss) income		(1.5)		368.6		70.7		383.4
Net income												Net income	136.1		16.8		206.8		400.2
Net income attributed to non-controlling interests	Net income attributed to non-controlling interests	6.8		6.8		14.7		15.0				Net income attributed to non-controlling interests	7.4		9.4		22.1		24.4
Net (loss) income attributable to Delek		$	(8.3)	$	361.8	$	56.0	$	368.4
Net income attributable to Delek												Net income attributable to Delek	$	128.7	$	7.4	$	184.7	$	375.8

(1) This information is presented at a summary level for your reference. See the Condensed Consolidated Statements of Income in Item 1. to this Quarterly Report on Form 10-Q for more detail regarding our results of operations and net income ~~(loss)~~ per share.

(2) In the first quarter 2023, we reassessed the classification of certain expenses and made certain reclassification adjustments to better represent the nature of those expenses. Accordingly, we have made reclassifications to the prior period in order to conform to this revised current period classification, which resulted in a decrease in the prior period general and administrative expenses and an increase in the prior period operating expenses of approximately ~~$4.2~~$3.1 million and ~~$7.1~~$10.2 million for the three and ~~six~~nine months ended ~~June~~September 30, 2022.

We report operating results in three reportable segments:

•Refining

•Logistics

•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 EBITDA.

Results of Operations

Consolidated Results of Operations — Comparison of the Three and ~~Six~~Nine Months Ended ~~June~~September 30, 2023 versus the Three and ~~Six~~Nine Months Ended ~~June~~September 30, ~~2022.~~2022

Net Income ~~(Loss)~~

Q2Q3 2023 vs. Q2Q3 2022

Consolidated net ~~loss~~income for the ~~second~~third quarter of 2023 was ~~$1.5~~$136.1 million compared to net income of ~~$368.6~~$16.8 million for the ~~second~~third quarter of 2022. Consolidated net ~~loss~~income attributable to Delek for the ~~second~~third quarter of ~~June~~September 30, 2023 was ~~$8.3~~$128.7 million, or ~~$(0.13)~~$1.98 per basic share, compared to a net income of ~~$361.8~~$7.4 million, or ~~$5.11~~$0.11 per basic share, for the ~~second~~third quarter 2022. Explanations for significant drivers impacting net income as compared to the comparable period of the prior year are discussed in the sections below.


3941 \|

Management's Discussion and Analysis

YTD 2023 vs. YTD 2022

Consolidated net income for the ~~six~~nine months ended ~~June~~September 30, 2023 was ~~$70.7~~$206.8 million compared to a net income of ~~$383.4~~$400.2 million for the ~~six~~nine months ended ~~June~~September 30, 2022. Consolidated net income attributable to Delek for the ~~six~~nine months ended ~~June~~September 30, 2023 was ~~$56.0~~$184.7 million, or ~~$0.84~~$2.80 per basic share, compared to income of ~~$368.4~~$375.8 million, or ~~$5.12~~$5.26 per basic share, for the ~~six~~nine months ended ~~June~~September 30, 2022. 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

Q2Q3 2023 vs. Q2Q3 2022

In the ~~second~~third quarter of 2023 and 2022, we generated net revenues of ~~$4,195.6~~$4,748.4 million and ~~$5,982.6~~$5,324.9 million, respectively, a decrease of ~~$1,787.0~~$576.5 million, or ~~29.9%~~10.8%. The decrease in net revenues was primarily driven by the following factors:

•in our refining segment, decreases in the average price of U.S. Gulf Coast gasoline of ~~31.1%~~2.5%, ULSD of ~~40.2%~~14.9%, and HSD of ~~57.4%~~28.7%, partially offset by an increase in sales volume (including purchased product);

•in our logistics segment, decreases in the average volumes of gasoline ~~and diesel~~ sold and in the average sales price per gallon of diesel and gasoline sold in our West Texas marketing operations, partially offset by increased volumes from the Midland Gathering operations and ~~incremental revenues from the~~ Delaware Gathering ~~Acquisition;~~operations; and

•in our retail segment, a decrease in total fuel sales primarily attributable to a decrease of ~~$1.06~~$0.24 in average price charged per gallon sold ~~partially offset by an increase~~and a decrease in merchandise sales primarily driven by the same-store sales ~~increase~~decrease of ~~0.1%~~1.9%.

YTD 2023 vs. YTD 2022

We generated net revenues of ~~$8,119.9~~$12,868.3 million and ~~$10,441.7~~$15,766.6 million during the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively, a decrease of ~~$2,321.8~~$2,898.3 million, or ~~22.2%~~18.4%. The decrease in net revenues was primarily due to the following:

•in our refining segment, decreases in ~~volume sold and decreases in~~ the average price of U.S. Gulf Coast gasoline of ~~22.5%~~16.4%, ULSD of ~~25.0%~~21.5%, and HSD of ~~44.7%~~39.6% and decreases in wholesale ~~activity; and~~activity, partially offset by an increase in sales volume (including purchased product);

•in our retail segment, a decrease in total fuel sales primarily attributable to a ~~$0.69~~$0.53 decrease in average price charged per gallon sold, partially offset by an increase in merchandise sales primarily driven by the same-store sales increase of ~~2.4%.~~1.1%; and

~~These decreases were partially offset by the following:~~

•in our logistics segment, increased volumes from the Midland Gathering operations and incremental revenues from the Delaware Gathering Acquisition, partially offset by decreases in the average volumes of diesel ~~and gasoline~~ sold and in the average sales price per gallon of diesel and gasoline sold in our West Texas marketing operations.

Total Operating Costs and Expenses

Cost of Materials and Other

Q2Q3 2023 vs. Q2Q3 2022

Cost of materials and other was ~~$3,766.6~~$4,122.1 million for the ~~second~~third quarter of 2023 compared to ~~$5,082.6~~$4,916.0 million for the ~~second~~third quarter of 2022, a decrease of ~~$1,316.0~~$793.9 million, or ~~25.9%~~16.1%. The net decrease in cost of materials and other was primarily driven by the following:

•decreases in cost of crude oil feedstocks at the refineries, including a ~~32.3% decrease~~10.0% decreases in the average cost of WTI Cushing crude oil and a ~~32.2%~~10.2% decrease in the average cost of WTI Midland crude oil;

•decreases in the average diesel volumes sold and average cost per gallon of gasoline and diesel sold in our logistics segment; and

•a decrease in retail cost of materials and other due to ~~26.9%~~9.0% decrease in average cost per gallon sold applied to ~~higher~~lower fuel sales volumes.

YTD 2023 vs. YTD 2022

Cost of materials and other was ~~$7,206.2~~$11,328.3 million for the ~~six~~nine months ended ~~June~~September 30, 2023, compared to ~~$9,235.1~~$14,151.1 million for ~~six~~nine months ended ~~June~~September 30, 2022, a decrease of ~~$2,028.9~~$2,822.8 million, or ~~22.0%~~19.9%. The net decrease in cost of materials and other primarily related to the following:

•a decrease in the cost of crude oil feedstocks at the refineries, including a ~~26.7%~~21.5% decrease in the average cost of WTI Cushing crude oil and a ~~26.6%~~21.3% decrease in the average cost of WTI Midland crude oil and decreased wholesale activity;

•decreases in the average diesel volumes sold and average cost per gallon of gasoline and diesel sold, partially offset by incremental cost of materials and other from the Delaware Gathering Acquisition in our logistics segment; and

•a decrease in retail cost of materials and other due to ~~18.5%~~15.4% decrease in average cost per gallon sold applied to ~~higher~~lower fuel sales volumes.


4042 \|

Management's Discussion and Analysis

Operating Expenses

Q2Q3 2023 vs. Q2Q3 2022

Operating expenses (included in both cost of sales and other operating expenses) were ~~$219.8~~$240.4 million for the ~~second~~third quarter of 2023 compared to ~~$226.7~~$229.5 million for the ~~second~~third quarter of ~~2022, a decrease of $6.9 million, or 3.0%. The decrease in operating expenses was primarily driven by the following:~~

•~~lower natural gas prices in 2023.~~

~~These decreases were partially offset by the following:~~

•~~an increase in maintenance costs including costs related to our Safety Action Plan, which we expect will continue at least through the end of 2023.~~

~~YTD 2023 vs. YTD 2022~~

~~Operating expenses (included in both cost of sales and other operating expenses) were $417.6 million for the six months ended June 30, 2023 compared to $396.5 million in six months ended June 30,~~ 2022, an increase of ~~$21.1~~$10.9 million, or ~~5.3%~~4.7%. The increase in operating expenses was primarily driven by the following:

•an increase in maintenance costs including costs related to our Safety Action Plan, which we expect will continue at least through the end of 2023;

•an additional $8.0 million expense for uncovered litigation, claims and assessments associated with the 2021 El Dorado refinery fire.

These increases were partially offset by the following:

•lower natural gas prices in 2023.

YTD 2023 vs. YTD 2022

Operating expenses (included in both cost of sales and other operating expenses) were $658.0 million for the nine months ended September 30, 2023 compared to $626.0 million in nine months ended September 30, 2022, an increase of $32.0 million, or 5.1%. The increase in operating expenses was primarily driven by the following:

•an increase in maintenance costs including costs related to our Safety Action Plan, which we expect will continue at least through the end of 2023;

•an additional $8.0 million expense for uncovered litigation, claims and assessments associated with the 2021 El Dorado refinery fire; and

•an increase in employee costs.

These increases were partially offset by the following:

•lower natural gas prices in 2023.

General and Administrative Expenses

Q2Q3 2023 vs. Q2Q3 2022

General and administrative expenses were ~~$75.8~~$72.0 million for the ~~second~~third quarter of 2023 compared to ~~$122.3~~$59.3 million for the ~~second~~third quarter of 2022, ~~a decrease~~an increase of ~~$46.5~~$12.7 million, or ~~38.0%~~21.4%. The ~~decrease~~increase was primarily driven by ~~a decrease~~an increase in employee costs including incentive compensation costs and restructuring costs, partially offset by no ~~transactions~~transaction costs related to the Delaware Gathering Acquisition in the 2023 period.

YTD 2023 vs. YTD 2022

General and administrative expenses were ~~$147.3~~$219.3 million for the ~~six~~nine months ended ~~June~~September 30, 2023 compared to ~~$172.5~~$231.8 million in ~~six~~nine months ended ~~June~~September 30, 2022, a decrease of ~~$25.2~~$12.5 million, or ~~14.6%~~5.4%. The decrease was primarily driven by a decrease in employee costs including incentive compensation costs and no ~~transactions~~transaction costs related to the Delaware Gathering Acquisition in the 2023 ~~period.~~period, partially offset by restructuring costs.

Depreciation and Amortization

Q2Q3 2023 vs. Q2Q3 2022

Depreciation and amortization (included in both cost of sales and other operating expenses) was ~~$89.4~~$91.3 million for the ~~second~~third quarter of 2023 compared to ~~$68.0~~$72.9 million for the ~~second~~third quarter of 2022, an increase of ~~$21.4~~$18.4 million, or ~~31.5%~~25.2%. The increase was a result of a general increase in our fixed asset base due to capital projects and turnarounds completed since the first quarter of 2022.

YTD 2023 vs. YTD 2022

Depreciation and amortization (included in both cost of sales and other operating expenses) was $264.1 million and $209.2 million for the nine months ended September 30, 2023 and 2022, respectively, an increase of $54.9 million, or 26.2%. The increase was a result of a general increase in our fixed asset base due to capital projects and turnarounds completed since the first quarter of 2022 and depreciation and amortization attributable to the Delaware Gathering Acquisition.

~~YTD 2023 vs. YTD 2022~~

Depreciation and amortization (included in both cost of sales and other operating expenses) was $172.8 million and $136.3 million for the six months ended June 30, 2023 and 2022, respectively, an increase of $36.5 million, or 26.8%. The increase was a result of a general increase in our fixed asset base due to capital projects and turnarounds completed since the first quarter of 2022 and amortization attributable to the Delaware Gathering Acquisition.

Other Operating Income, Net

Q2Q3 2023 vs. Q2Q3 2022

Other operating income, net decreased by ~~$4.2~~$3.7 million in the ~~second~~third quarter of 2023 to ~~$6.1~~$2.1 million compared to ~~$10.3~~$5.8 million in the ~~second~~third quarter of 2022. The decrease was primarily due to a ~~$3.9~~$5.1 million decrease in insurance recoveries related to the fire and freeze events that occurred during the first quarter ~~2021.~~2021 and fire event that occurred in the fourth quarter 2022.


4143 \|

Management's Discussion and Analysis

YTD 2023 vs. YTD 2022

Other operating income, net was ~~$16.9~~$19.0 million and ~~$38.7~~$44.5 million for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively, a decrease of ~~$21.8~~$25.5 million, primarily due to ~~an $8.8~~a $13.9 million decrease in insurance recoveries related to the fire and freeze events that occurred during the first quarter 2021 and fire event that occurred in the fourth quarter 2022 and decreased hedge gains realized in 2023 compared to 2022 associated with our trading derivatives.

Non-Operating Expenses, Net

Interest Expense, Net

Q2Q3 2023 vs. Q2Q3 2022

Interest expense, net increased by ~~$36.8~~$31.6 million, or ~~84.4%~~62.3%, to ~~$80.4~~$82.3 million in the ~~second~~third quarter of 2023 compared to ~~$43.6~~$50.7 million in the ~~second~~third quarter of 2022, primarily driven by the following:

•an increase in the average effective interest rate of ~~492~~485 basis points in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022 (where effective interest rate is calculated as interest expense divided by the net average borrowings/obligations outstanding); and

•~~an increase~~a decrease in net average borrowings outstanding (including the obligations under the supply and offtake agreements which have an associated interest charge) of approximately ~~$92.6~~$256.8 million in the ~~second~~third quarter of 2023 (calculated as a simple average of beginning borrowings/obligations and ending borrowings/obligations for the period) compared to the ~~second~~third quarter of 2022.

YTD 2023 vs. YTD 2022

Interest expense, net was ~~$156.9~~$239.2 million in the ~~six~~nine months ended ~~June~~September 30, 2023, compared to ~~$82.0~~$132.7 million for ~~six~~nine months ended ~~June~~September 30, 2022, an increase of ~~$74.9~~$106.5 million, or ~~91.3%~~80.3% primarily due to the following:

•an increase in the average effective interest rate of ~~444~~611 basis points during the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022 (where effective interest rate is calculated as interest expense divided by the net average borrowings/obligations outstanding); and

•an increase in net average borrowings outstanding (including the obligations under the supply and offtake agreements which have an associated interest charge) of approximately ~~$283.0~~$350.2 million during the ~~six~~nine months ended ~~June~~September 30, 2023 (calculated as a simple average of beginning borrowings/obligations and ending borrowings/obligations for the period) compared to the ~~six~~nine months ended ~~June~~September 30, 2022.

Results from Equity Method Investments

Q2Q3 2023 vs. Q2Q3 2022

We recognized income from equity method investments of ~~$25.5~~$27.0 million during the ~~second~~third quarter of 2023, compared to ~~$15.7~~$17.8 million for the ~~second~~third quarter of 2022, an increase of ~~$9.8~~$9.2 million. This increase was primarily driven by the following:

•an increase in income from our asphalt terminal equity method investment due to improved margins; and

•an increase in income from our investment in W2W Holdings LLC to $6.9 million in the third quarter of 2023 from $1.2 million in the third quarter of 2022.

YTD 2023 vs. YTD 2022

We recognized income from equity method investments of $67.1 million for the nine months ended September 30, 2023, compared to $44.4 million for the nine months ended September 30, 2022, an increase of $22.7 million. This increase was primarily driven by the following:

•an increase in income from our asphalt terminal equity method investment due to higher volumes and resulting revenue increases; and

•an increase in income from our investment in W2W Holdings LLC to ~~$6.8~~$18.2 million during the nine months ended September 30, 2023 from $5.4 million in the ~~second quarter of 2023 from $2.1 million in the second quarter of 2022.~~

~~YTD 2023 vs. YTD 2022~~

~~We recognized income from equity method investments of $40.1 million for the six~~nine months ended ~~June 30, 2023, compared to $26.6 million for the six months ended June 30, 2022, an increase of $13.5 million. This increase was primarily driven by the following:~~

•~~an increase in income from our asphalt terminal equity method investment due to higher volumes and resulting revenue increases; and~~

•~~an increase in income from our investment in W2W Holdings LLC to $11.3 million during the six months ended June 30, 2023 from $4.2 million in the six months ended June~~September 30, 2022.

Income Taxes

Q2Q3 2023 vs. Q2Q3 2022

For the ~~second~~third quarter of 2023, we recorded ~~an income tax benefit of $3.8 million compared to~~ income tax expense of ~~$100.4~~$31.5 million compared to $4.0 million for the ~~second~~third quarter of 2022, primarily driven by the following:

•~~a decrease~~an increase in pre-tax net income of ~~$474.3~~$146.8 million; and

•Our effective tax rates were 71.7% and 21.4% for the three months ended June 30, 2023 and 2022, respectively, due to the impact of fixed dollar favorable permanent differences on the tax rate and changes in the second quarter estimated annual effective tax rate applied to year to date earnings.


4244 \|

Management's Discussion and Analysis

•Our effective tax rates were 18.8% and 19.2% for the three months ended September 30, 2023 and 2022, respectively, due to the impact of fixed dollar permanent differences on the tax rate and changes to valuation allowances on state attributes.

YTD 2023 vs. YTD 2022

For the ~~six~~nine months ended ~~June~~September 30, 2023, we recorded income tax expense of ~~$12.0~~$43.5 million compared to ~~$103.5~~$107.5 million for the ~~six~~nine months ended ~~June~~September 30, 2022, primarily driven by the following:

•a decrease in pre-tax net income of ~~$404.2~~$257.4 million, and

•Our effective tax rates were ~~14.5%~~17.4% and ~~21.3%~~21.2% for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively, due to the impact of fixed dollar favorable permanent differences on the tax rate.


4345 \|

Management's Discussion and Analysis


Refining Segment

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


Selected Refining Financial Information	Selected Refining Financial Information									Selected Refining Financial Information
		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,		Nine Months Ended September 30,
		2023		2022		2023		2022					2023		2022		2023		2022
Revenues	Revenues	$	4,052.5	$	5,874.9	$	7,847.0	$	10,267.2			Revenues	$	4,624.5	$	5,167.4	$	12,471.5	$	15,434.6
Cost of materials and other	Cost of materials and other	3,783.3		5,096.5		7,242.1		9,286.7				Cost of materials and other	4,167.8		4,913.7		11,409.9		14,200.4
Refining Margin	Refining Margin	$	269.2	$	778.4	$	604.9	$	980.5			Refining Margin	$	456.7	$	253.7	$	1,061.6	$	1,234.2

Operating expenses (excluding depreciation and amortization)	Operating expenses (excluding depreciation and amortization)	$	153.8	$	169.4	$	292.9	$	292.1			Operating expenses (excluding depreciation and amortization)	$	166.5	$	175.4	$	459.4	$	467.5

Refining segment EBITDA	Refining segment EBITDA	$	110.5	$	587.9	$	302.6	$	667.9			Refining segment EBITDA	$	285.1	$	90.3	$	587.7	$	758.2

Factors Impacting Refining Profitability

Our profitability in the refining segment is substantially determined by the difference between the cost of the crude oil feedstocks we purchase and the price of the refined products we sell, referred to as the "crack spread", "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. Our crude slate is predominantly comprised of WTI crude oil. Therefore, favorable differentials of WTI compared to other crude will favorably impact our operating results, and vice versa. Additionally, because of our gathering system presence in the Midland area and the significant source of crude specifically from that region into our network, 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 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 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 and LLS. The Brent less LLS spread represents the differential between the average per barrel price of Brent 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.

Finally, Refining EBITDA is impacted by regulatory costs associated with the cost of RINs as well as energy costs, including the cost of natural gas. In periods of unfavorable regulatory sentiment, RINs prices can increase at higher rates than crack spreads, or even when crack spreads are declining. This can be particularly impactful on smaller refineries, where the operating cost structure does not have as much scalability as larger refineries. Additionally, volatility in energy costs, which are captured in our operating expenses and impact our Refining EBITDA, can significantly impact our ability to capture crack spreads, with natural gas representing the most significant component. Within Delek’s geographic footprint, we source the majority of our natural gas from the Gulf Coast, and secondarily from the Permian, and we do not currently have the capability at our refineries to switch our energy consumption to utilize alternative sources of fuel. For this reason, unfavorable Gulf Coast (Henry Hub) differentials can impact our crack spread capture.

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 largely depends on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other


46 \|

Management's Discussion and Analysis

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.


~~44 \|~~

~~Management's Discussion and Analysis~~

In addition to the above, it continues to be a strategic and operational objective to manage price and supply risk related to crude oil that is used in refinery production, and to develop strategic sourcing relationships. For that purpose, from a pricing perspective, 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 our RINs Obligation. Additionally, from a sourcing perspective, we often enter into purchase and sale contracts with vendors and customers or take physical or financial commodity positions for crude oil that may not be used immediately in production, but that may be used to manage the overall supply and availability of crude expected to ultimately be needed for production and/or to meet minimum requirements under strategic pipeline arrangements, and also to optimize and hedge availability risks associated with crude that we ultimately expect to use in production. Such transactions are inherently based on certain assumptions and judgments made about the current and possible future availability of crude. Therefore, when we take physical or financial positions for optimization purposes, our intent is generally to take offsetting positions in quantities and at prices that will advance these objectives while minimizing our positional and financial statement risk. However, because of the volatility of the market in terms of pricing and availability, it is possible that we may have material positions with timing differences or, more rarely, that we are unable to cover a position with an offsetting position as intended. Such differences could have a material impact on the classification of resulting gains/losses, assets or liabilities, and could also significantly impact Refining EBITDA.


Refinery Statistics	Refinery Statistics									Refinery Statistics

		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,

		2023		2022		2023		2022					2023			2022		2023		2022

Total Refining Segment	Total Refining Segment											Total Refining Segment
Days in period	Days in period	91		91		181		181				Days in period	92			92		273		273
Total sales volume - refined product (average bpd) (1)	Total sales volume - refined product (average bpd) (1)	305,688		305,300		288,795		304,587				Total sales volume - refined product (average bpd) (1)	307,626			312,877		295,141		307,380
Total production (average bpd)	Total production (average bpd)	291,715		295,457		279,230		290,784				Total production (average bpd)	303,399			300,235		287,375		293,970
Crude oil	Crude oil	282,493		294,702		265,441		283,491				Crude oil	294,726			299,973		275,310		289,046
Other feedstocks	Other feedstocks	12,988		2,602		16,642		8,703				Other feedstocks	11,222			2,276		14,815		6,537
Total throughput (average bpd):	Total throughput (average bpd):	295,481		297,304		282,083		292,194				Total throughput (average bpd):	305,948			302,249		290,125		295,583

Crude Slate: (% based on amount received in period)	Crude Slate: (% based on amount received in period)											Crude Slate: (% based on amount received in period)
WTI crude oil	WTI crude oil	75.9	%	62.2	%	73.2	%	62.4	%			WTI crude oil	73.4	%		75.2	%	73.3	%	67.1	%
Gulf Coast Sweet Crude	Gulf Coast Sweet Crude	4.0	%	10.8	%	4.3	%	10.1	%			Gulf Coast Sweet Crude	3.3	%		5.3	%	4.0	%	8.4	%
Local Arkansas crude oil	Local Arkansas crude oil	3.9	%	4.3	%	4.2	%	4.4	%			Local Arkansas crude oil	4.0	%		3.5	%	4.1	%	4.1	%
Other	Other	16.2	%	22.7	%	18.3	%	23.1	%			Other	19.3	%		16.0	%	18.6	%	20.4	%

Crude utilization (% based on nameplate capacity)	Crude utilization (% based on nameplate capacity)	93.5	%	97.6	%	87.9	%	93.9	%			Crude utilization (% based on nameplate capacity)	97.6	%		99.3	%	91.2	%	95.7	%


4547 \|

Management's Discussion and Analysis


Refinery Statistics (continued)	Refinery Statistics (continued)													Refinery Statistics (continued)
		Three Months Ended June 30,						Six Months Ended June 30,							Three Months Ended September 30,					Nine Months Ended September 30,

		2023			2022			2023			2022						2023				2022			2023			2022

Tyler, TX Refinery	Tyler, TX Refinery															Tyler, TX Refinery
Days in period	Days in period	91			91			181			181					Days in period	92				92			273			273
Products manufactured (average bpd):	Products manufactured (average bpd):															Products manufactured (average bpd):
Gasoline	Gasoline	37,672			32,645			28,276			34,924					Gasoline	35,615				35,210			30,750			35,021
Diesel/Jet	Diesel/Jet	33,029			30,271			23,091			29,644					Diesel/Jet	34,620				33,844			26,976			31,060
Petrochemicals, LPG, natural gas liquids ("NGLs")	Petrochemicals, LPG, natural gas liquids ("NGLs")	3,031			1,983			1,890			2,116					Petrochemicals, LPG, natural gas liquids ("NGLs")	3,429				2,246			2,409			2,160
Other	Other	1,829			1,824			1,803			1,748					Other	1,959				2,032			1,856			1,844
Total production	Total production	75,561			66,723			55,060			68,432					Total production	75,623				73,332			61,991			70,085
Throughput (average bpd):	Throughput (average bpd):															Throughput (average bpd):
Crude Oil	Crude Oil	72,955			66,681			51,501			66,559					Crude Oil	74,877				74,796			59,379			69,335
Other feedstocks	Other feedstocks	3,955			552			4,323			2,128					Other feedstocks	1,118				(1,123)			3,243			1,032
Total throughput	Total throughput	76,910			67,233			55,824			68,687					Total throughput	75,995				73,673			62,622			70,367
Per barrel of throughput:	Per barrel of throughput:															Per barrel of throughput:
Operating expenses (2)	Operating expenses (2)	$	3.78		$	6.20		$	5.29		$	5.40				Operating expenses (2)	$	4.74			$	7.06		$	5.06		$	5.99
Crude Slate: (% based on amount received in period)	Crude Slate: (% based on amount received in period)															Crude Slate: (% based on amount received in period)
WTI crude oil	WTI crude oil	86.5		%	83.8		%	78.7		%	85.4		%			WTI crude oil	76.8		%		86.4		%	78.1		%	85.9		%
East Texas crude oil	East Texas crude oil	13.5		%	16.2		%	21.3		%	14.6		%			East Texas crude oil	23.2		%		13.6		%	21.9		%	14.1		%

El Dorado, AR Refinery	El Dorado, AR Refinery															El Dorado, AR Refinery
Days in period	Days in period	91			91			181			181					Days in period	92				92			273			273
Products manufactured (average bpd):	Products manufactured (average bpd):															Products manufactured (average bpd):
Gasoline	Gasoline	34,220			39,347			36,121			38,118					Gasoline	39,361				40,577			37,213			38,946
Diesel	Diesel	27,948			32,855			27,830			31,027					Diesel	31,927				31,372			29,211			31,143
Petrochemicals, LPG, NGLs	Petrochemicals, LPG, NGLs	1,521			1,549			1,406			1,285					Petrochemicals, LPG, NGLs	1,875				1,347			1,564			1,306
Asphalt	Asphalt	6,641			8,181			7,177			7,655					Asphalt	7,893				8,503			7,418			7,941
Other	Other	1,185			805			967			795					Other	1,168				848			1,034			813
Total production	Total production	71,515			82,737			73,501			78,880					Total production	82,224				82,647			76,440			80,149
Throughput (average bpd):	Throughput (average bpd):															Throughput (average bpd):
Crude Oil	Crude Oil	71,449			81,510			72,040			76,827					Crude Oil	81,671				80,711			75,286			78,136
Other feedstocks	Other feedstocks	2,011			2,221			3,278			3,079					Other feedstocks	2,611				3,301			3,053			3,154
Total throughput	Total throughput	73,460			83,731			75,318			79,906					Total throughput	84,282				84,012			78,339			81,290
Per barrel of throughput:	Per barrel of throughput:															Per barrel of throughput:
Operating expenses (2)	Operating expenses (2)	$	5.00		$	5.07		$	4.73		$	4.63				Operating expenses (2)	$	4.36			$	4.83		$	4.60		$	4.70
Crude Slate: (% based on amount received in period)	Crude Slate: (% based on amount received in period)															Crude Slate: (% based on amount received in period)
WTI crude oil	WTI crude oil	68.4		%	53.1		%	65.2		%	43.2		%			WTI crude oil	71.9		%		68.4		%	67.6		%	52.1		%
Local Arkansas crude oil	Local Arkansas crude oil	16.6		%	15.6		%	15.6		%	16.4		%			Local Arkansas crude oil	13.4		%		14.0		%	14.8		%	15.5		%
Other	Other	15.0		%	31.3		%	19.2		%	40.4		%			Other	14.7		%		17.6		%	17.6		%	32.4		%


4648 \|

Management's Discussion and Analysis


Refinery Statistics (continued)	Refinery Statistics (continued)													Refinery Statistics (continued)
		Three Months Ended June 30,						Six Months Ended June 30,							Three Months Ended September 30,		Nine Months Ended September 30,

		2023			2022			2023			2022						2023			2022			2023			2022

Big Spring, TX Refinery	Big Spring, TX Refinery															Big Spring, TX Refinery
Days in period	Days in period	91			91			181			181					Days in period	92			92			273			273
Products manufactured (average bpd):	Products manufactured (average bpd):															Products manufactured (average bpd):
Gasoline	Gasoline	33,582			34,918			36,032			33,912					Gasoline	29,274			34,431			33,755			34,087
Diesel/Jet	Diesel/Jet	20,774			27,043			23,194			24,877					Diesel/Jet	23,607			26,020			23,333			25,262
Petrochemicals, LPG, NGLs	Petrochemicals, LPG, NGLs	3,034			3,537			3,083			3,436					Petrochemicals, LPG, NGLs	3,723			3,524			3,299			3,466
Asphalt	Asphalt	1,630			1,406			1,636			1,642					Asphalt	2,220			1,701			1,833			1,662
Other	Other	1,907			1,410			2,272			1,345					Other	5,272			1,342			3,283			1,344
Total production	Total production	60,927			68,314			66,217			65,212					Total production	64,096			67,018			65,503			65,821
Throughput (average bpd):	Throughput (average bpd):															Throughput (average bpd):
Crude oil	Crude oil	59,240			70,662			63,590			65,675					Crude oil	61,046			70,955			62,733			67,455
Other feedstocks	Other feedstocks	3,020			(1,093)			3,818			315					Other feedstocks	3,865			(3,189)			3,834			(866)
Total throughput	Total throughput	62,260			69,569			67,408			65,990					Total throughput	64,911			67,766			66,567			66,589
Per barrel of refined throughput:	Per barrel of refined throughput:															Per barrel of refined throughput:
Operating expenses (2)	Operating expenses (2)	$	8.91		$	7.58		$	7.24		$	6.86				Operating expenses (2)	$	8.37		$	7.32		$	7.61		$	7.02
Crude Slate: (% based on amount received in period)	Crude Slate: (% based on amount received in period)															Crude Slate: (% based on amount received in period)
WTI crude oil	WTI crude oil	66.7		%	68.2		%	71.0		%	67.5		%			WTI crude oil	64.3		%	72.7		%	68.8		%	69.3		%
WTS crude oil	WTS crude oil	33.3		%	31.8		%	29.0		%	32.5		%			WTS crude oil	35.7		%	27.3		%	31.2		%	30.7		%

Krotz Springs, LA Refinery	Krotz Springs, LA Refinery															Krotz Springs, LA Refinery
Days in period	Days in period	91			91			181			181					Days in period	92			92			273			273
Products manufactured (average bpd):	Products manufactured (average bpd):															Products manufactured (average bpd):
Gasoline	Gasoline	41,191			31,298			41,517			31,979					Gasoline	38,361			32,371			40,454			32,111
Diesel/Jet	Diesel/Jet	31,968			32,419			32,373			31,711					Diesel/Jet	30,653			31,195			31,794			31,537
Heavy Oils	Heavy Oils	3,725			845			3,618			1,690					Heavy Oils	5,461			944			4,239			1,439
Petrochemicals, LPG, NGLs	Petrochemicals, LPG, NGLs	6,588			7,152			6,730			7,040					Petrochemicals, LPG, NGLs	6,079			6,768			6,510			6,948
Other	Other	240			5,970			214			5,840					Other	902			5,960			446			5,881
Total production	Total production	83,712			77,684			84,452			78,260					Total production	81,456			77,238			83,443			77,916
Throughput (average bpd):	Throughput (average bpd):															Throughput (average bpd):
Crude Oil	Crude Oil	78,848			75,849			78,309			74,430					Crude Oil	77,132			73,510			77,912			74,120
Other feedstocks	Other feedstocks	4,002			922			5,224			3,181					Other feedstocks	3,628			3,287			4,686			3,216
Total throughput	Total throughput	82,850			76,771			83,533			77,611					Total throughput	80,760			76,797			82,598			77,336
Per barrel of throughput:	Per barrel of throughput:															Per barrel of throughput:
Operating expenses (2)	Operating expenses (2)	$	4.74		$	6.14		$	4.97		$	5.12				Operating expenses (2)	$	5.00		$	5.97		$	5.00		$	5.41
Crude Slate: (% based on amount received in period)	Crude Slate: (% based on amount received in period)															Crude Slate: (% based on amount received in period)
WTI Crude	WTI Crude	77.4		%	49.4		%	78.5		%	56.6		%			WTI Crude	79.8		%	70.1		%	79.0		%	61.0		%
Gulf Coast Sweet Crude	Gulf Coast Sweet Crude	15.0		%	40.6		%	14.7		%	38.2		%			Gulf Coast Sweet Crude	11.2		%	23.2		%	13.5		%	33.3		%
Other	Other	7.6		%	10.0		%	6.8		%	5.2		%			Other	9.0		%	6.7		%	7.5		%	5.7		%

(1) Includes inter-refinery sales and sales to other segments which are eliminated in consolidation. See tables below.

(2) Reflects the prior period conforming reclassification adjustment between operating expenses and general and administrative expenses.


4749 \|

Management's Discussion and Analysis

Included in the refinery statistics above are the following ~~inter-refinery and~~ sales to other segments:

Inter-refinery Sales
Three Months Ended June 30, Six Months Ended June 30,
(in barrels per day) 2023 2022 2023 2022
El Dorado refined product sales to other Delek refineries — 1,531 — 1,201
Big Spring refined product sales to other Delek refineries — 470 — 554
Krotz Springs refined product sales to other Delek refineries — 1,061 — 783


Refinery Sales to Other Segments
	Three Months Ended September 30,		Nine Months Ended September 30,
(in barrels per day)	2023	2022	2023	2022



El Dorado refined product sales to other Delek segments	—	—	—	5
Big Spring refined product sales to other Delek segments	—	21,565	6,406	20,863

Refinery Sales to Other Segments
Three Months Ended June 30, Six Months Ended June 30,
(in barrels per day) 2023 2022 2023 2022
El Dorado refined product sales to other Delek segments — 9 — 8
Big Spring refined product sales to other Delek segments — 22,647 9,663 22,209


Pricing Statistics (average for the period presented)	Pricing Statistics (average for the period presented)									Pricing Statistics (average for the period presented)
		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,		Nine Months Ended September 30,
		2023		2022		2023		2022					2023		2022		2023		2022

WTI — Cushing crude oil (per barrel)	WTI — Cushing crude oil (per barrel)	$	73.57	$	108.74	$	74.78	$	102.02			WTI — Cushing crude oil (per barrel)	$	82.51	$	91.63	$	77.37	$	98.50
WTI — Midland crude oil (per barrel)	WTI — Midland crude oil (per barrel)	$	73.56	$	108.50	$	74.77	$	101.81			WTI — Midland crude oil (per barrel)	$	83.85	$	93.41	$	78.63	$	99.87
WTS — Midland crude oil (per barrel)	WTS — Midland crude oil (per barrel)	$	73.55	$	109.06	$	74.48	$	101.92			WTS — Midland crude oil (per barrel)	$	83.01	$	92.17	$	77.34	$	98.58
LLS (per barrel)	LLS (per barrel)	$	75.67	$	110.25	$	77.27	$	103.92			LLS (per barrel)	$	84.88	$	94.07	$	79.82	$	100.58
Brent (per barrel)	Brent (per barrel)	$	77.74	$	111.84	$	79.94	$	104.93			Brent (per barrel)	$	85.92	$	97.69	$	81.96	$	102.48

U.S. Gulf Coast 5-3-2 crack spread (per barrel) - utilizing HSD	U.S. Gulf Coast 5-3-2 crack spread (per barrel) - utilizing HSD	$	9.79	$	34.05	$	13.22	$	26.12			U.S. Gulf Coast 5-3-2 crack spread (per barrel) - utilizing HSD	$	16.80	$	23.07	$	14.41	$	25.08
U.S. Gulf Coast 5-3-2 crack spread (per barrel) (1)	U.S. Gulf Coast 5-3-2 crack spread (per barrel) (1)	$	25.54	$	44.03	$	29.04	$	33.77			U.S. Gulf Coast 5-3-2 crack spread (per barrel) (1)	$	32.39	$	33.65	$	30.15	$	33.73
U.S. Gulf Coast 3-2-1 crack spread (per barrel) (1)	U.S. Gulf Coast 3-2-1 crack spread (per barrel) (1)	$	25.42	$	42.44	$	28.32	$	32.56			U.S. Gulf Coast 3-2-1 crack spread (per barrel) (1)	$	31.30	$	31.28	$	29.30	$	32.12
U.S. Gulf Coast 2-1-1 crack spread (per barrel) (1)	U.S. Gulf Coast 2-1-1 crack spread (per barrel) (1)	$	11.32	$	36.23	$	15.23	$	26.71			U.S. Gulf Coast 2-1-1 crack spread (per barrel) (1)	$	19.48	$	25.63	$	16.64	$	26.33

U.S. Gulf Coast Unleaded Gasoline (per gallon)	U.S. Gulf Coast Unleaded Gasoline (per gallon)	$	2.34	$	3.40	$	2.37	$	3.05			U.S. Gulf Coast Unleaded Gasoline (per gallon)	$	2.58	$	2.64	$	2.44	$	2.92
Gulf Coast Ultra low sulfur diesel (per gallon)	Gulf Coast Ultra low sulfur diesel (per gallon)	$	2.38	$	3.98	$	2.62	$	3.50			Gulf Coast Ultra low sulfur diesel (per gallon)	$	2.97	$	3.49	$	2.74	$	3.49
U.S. Gulf Coast high sulfur diesel (per gallon)	U.S. Gulf Coast high sulfur diesel (per gallon)	$	1.45	$	3.39	$	1.68	$	3.04			U.S. Gulf Coast high sulfur diesel (per gallon)	$	2.04	$	2.86	$	1.80	$	2.98
Natural gas (per MMBtu)	Natural gas (per MMBtu)	$	2.33	$	7.50	$	2.53	$	6.05			Natural gas (per MMBtu)	$	2.66	$	7.97	$	2.57	$	6.69

(1)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 (Argus pricing) WTI Cushing crude, U.S. Gulf Coast CBOB gasoline and U.S. Gulf Coast Pipeline No. 2 heating oil (ultra low sulfur diesel). For our Big Spring refinery, we compare our per barrel refining margin to the Gulf Coast 3-2-1 crack spread consisting of (Argus pricing) WTI Cushing crude, U.S. Gulf Coast CBOB gasoline and Gulf Coast ultra-low sulfur diesel. Starting in Q1 2023, for our Krotz Springs refinery, we compare our per barrel refining margin to the Gulf Coast 2-1-1 crack spread consisting of (Argus pricing) LLS crude oil, (Argus pricing) U.S. Gulf Coast CBOB gasoline and 50% of (Argus pricing) U.S. Gulf Coast Pipeline No. 2 heating oil (high sulfur diesel) and 50% of (Platts pricing) U.S. Gulf Coast Pipeline No. 2 heating oil (high sulfur diesel). Historical Gulf Coast 2-1-1 crack spread measures have been revised to conform to current period presentation. The Tyler refinery's crude oil input is primarily WTI Midland and East Texas, while the El Dorado refinery's crude input is primarily a 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.


4850 \|

Management's Discussion and Analysis

Refining Segment Operational Comparison of the Three and ~~Six~~Nine Months Ended ~~June~~September 30, 2023 versus the Three and ~~Six~~Nine Months Ended ~~June~~September 30, ~~2022.~~2022

Revenues

Q2Q3 2023 vs. Q2Q3 2022

Net revenues for the refining segment decreased by ~~$1,822.4~~$542.9 million, or ~~31.0%~~10.5%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022. The decrease was primarily driven by the following:

•a decrease in the average price of U.S. Gulf Coast gasoline of ~~31.1%~~2.5%, ULSD of ~~40.2%~~14.9%, and HSD of ~~57.4%~~28.7%; and

•a decrease in wholesale activity.

These decreases were partially offset by the following:

•an increase in sales volumes (including purchased products).

Net revenues included sales to our retail segment of ~~$111.5~~$117.0 million and ~~$160.1~~$132.1 million, sales to our logistics segment of ~~$92.0~~$115.1 million and ~~$143.9~~$124.7 million, and sales to our other segment of $0.0 million and ~~$8.3~~$6.1 million for the three months ended ~~June~~September 30, 2023 and ~~June~~September 30, 2022, respectively. We eliminate this intercompany revenue in consolidation.

YTD 2023 vs. YTD 2022

Revenues for the refining segment decreased ~~$2,420.2~~$2,963.1 million, or ~~23.6%~~19.2%, in the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022. The decrease was primarily driven by the following:

•a decrease in the average price of U.S. Gulf Coast gasoline of ~~22.5%~~16.4%, ULSD of ~~25.0%~~21.5%, and HSD of ~~44.7%~~39.6%;

•~~a decrease in total sales volumes primarily driven by turnaround activities at the Tyler refinery in the first quarter 2023;~~ and

•a decrease in wholesale activity.

These decreases were partially offset by the following:

•an increase in sales volumes (including purchased products).

Revenues included sales to our retail segment of ~~$214.1~~$331.0 million and ~~$271.9~~$404.0 million, sales to our logistics segment of ~~$183.1~~$298.3 million and ~~$249.8~~$374.5 million and sales to the other segment of $0.0 million and ~~$16.4~~$22.5 million for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively. We eliminate this intercompany revenue in consolidation.

Cost of Materials and Other

Q2Q3 2023 vs. Q2Q3 2022

Cost of materials and other decreased by ~~$1,313.2~~$745.9 million, or ~~25.8%~~15.2%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022. The decrease was primarily driven by the following:

•decreases in the cost of WTI Cushing crude oil, from an average of ~~$108.74~~$91.63 per barrel to an average of ~~$73.57,~~$82.51, or ~~32.3%~~10.0%, and decreases in the cost of WTI Midland crude oil, from an average of ~~$108.50~~$93.41 per barrel to an average of ~~$73.56,~~$83.85, or ~~32.2%~~10.2%;

•favorable inventory impacts; and

•a decrease in wholesale activity.

These decreases were partially offset by the following:

•an increase in sales volumes (including purchased products).


51 \|

Management's Discussion and Analysis

YTD 2023 vs. YTD 2022

Cost of materials and other decreased ~~$2,044.6~~$2,790.5 million, or ~~22.0%~~19.7%, in the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022. This decrease was primarily driven by the following:

•decreases in the cost of WTI Cushing crude oil, from an average of ~~$102.02~~$98.50 per barrel to an average of ~~$74.78,~~$77.37, or ~~26.7%~~21.5%, and decreases in the cost of WTI Midland crude oil, from an average of ~~$101.81~~$99.87 per barrel to an average of ~~$74.77,~~$78.63, or ~~26.6%~~21.3%;

•~~a decrease in sales volumes;~~ and

•a decrease in wholesale activity.

These decreases were partially offset by the following:


~~49 \|~~

~~Management's Discussion and Analysis~~

•an increase in sales volumes (including purchased products).

Our refining segment purchases finished product from our logistics segment and 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 costs and fees were ~~$132.6~~$156.0 million and ~~$123.8~~$126.1 million during the three months ended ~~June~~September 30, 2023 and 2022, respectively. These costs and fees were ~~$257.2~~$413.2 million and ~~$247.2~~$373.3 million during the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively. We eliminate these intercompany fees in consolidation.

Refining Margin

Q2Q3 2023 vs. Q2Q3 2022

Refining segment margin ~~decreased~~increased by ~~$509.2~~$203.0 million, or ~~65.4%~~80.0%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022, with a refining margin percentage of ~~6.6%~~9.9% as compared to ~~13.2%~~4.9% for the ~~second~~third quarter of 2023 and 2022, respectively, primarily driven by the following:

•an increase in sales volume (including purchased products);

•an increase in utilization;

•favorable inventory impacts;

•lower natural gas prices; and

•a ~~42.0%~~3.7% decrease in the 5-3-2 crack spread (the primary measure for the Tyler refinery and El Dorado refinery), a ~~40.1% decrease~~0.1% increase in the average Gulf Coast 3-2-1 crack spread (the primary measure for the Big Spring refinery), and a ~~68.8%~~24.0% decrease in the average Gulf Coast 2-1-1 crack spread (the primary measure for the Krotz Springs refinery)~~; and~~

•~~a decrease in utilization.~~.

YTD 2023 vs. YTD 2022

Refining margin decreased by ~~$375.6~~$172.6 million, or ~~38.3%~~14.0%, for the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022, with a refining margin percentage of ~~7.7%~~8.5% as compared to ~~9.5%~~8.0% for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively, primarily driven by the following:

•a ~~14.0%~~10.6% decrease in the 5-3-2 crack spread (the primary measure for the Tyler refinery and El Dorado refinery), ~~a 13.0%~~an 8.8% decrease in the average Gulf Coast 3-2-1 crack spread (the primary measure for the Big Spring refinery) and a ~~43.0%~~36.8% decrease in the average Gulf Coast 2-1-1 crack spread (the primary measure for the Krotz Springs refinery);

•lower natural gas prices; and

•~~a decrease~~an increase in ~~total~~ sales ~~volumes primarily driven by turnaround activities at the Tyler refinery in the first quarter of 2023.~~volume (including purchased products).


5052 \|

Management's Discussion and Analysis

Operating Expenses

Q2Q3 2023 vs. Q2Q3 2022

Operating expenses decreased by ~~$15.6~~$8.9 million, or ~~9.2%~~5.1%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022. The decrease in operating expenses was primarily driven by the following:

•lower natural gas in 2023.

These decreases were partially offset by the following:

•increase in outside service and maintenance costs including costs related to our Safety Action Plan, which we expect will continue at least through the end of 2023.

YTD 2023 vs. YTD 2022

Operating expenses ~~increased $0.8~~decreased by $8.1 million, or ~~0.3%~~1.7%, in the ~~six~~nine months ended ~~June~~September 30, 2023, compared to ~~six~~nine months ended ~~June~~September 30, 2022. The ~~increase~~decrease in operating expenses was primarily driven by the following:

•lower natural gas in 2023.

These decreases were partially offset by the following:

•higher employee, outside service and maintenance costs including costs related to our Safety Action Plan, which we expect will continue at least through the end of 2023.

~~These increases were partially offset by the following:~~

•~~lower natural gas prices in 2023.~~

EBITDA

Q2Q3 2023 vs. Q2Q3 2022

EBITDA ~~decreased~~increased by ~~$477.4~~$194.8 million, for the three months ended ~~June~~September 30, 2023 compared to the three months ended ~~June~~September 30, 2022, primarily due to an increase in refining margin driven by increased sales volume (including purchased products) and lower natural gas prices, partially offset by decreased crack spreads.

YTD 2023 vs. YTD 2022

EBITDA decreased by $170.5 million, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022, primarily due to a decrease in refining margin driven by decreased crack spreads, partially offset by ~~lower natural gas prices.~~

~~YTD 2023 vs. YTD 2022~~

EBITDA decreased by $365.3 million, for the six months ended June 30, 2023 compared to the six months ended June 30, 2022, primarily due to a decrease in refining margin driven by decreased crack spreads and decreasedincreased sales volume ~~partially offset by~~(including purchased products) and lower natural gas prices.


5153 \|

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):


Selected Logistics Financial and Operating Information	Selected Logistics Financial and Operating Information									Selected Logistics Financial and Operating Information
		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,		Nine Months Ended September 30,
		2023		2022		2023		2022					2023		2022		2023		2022
Revenues	Revenues	$	246.9	$	266.7	$	490.4	$	473.3			Revenues	$	275.9	$	294.1	$	766.3	$	767.4
Cost of materials and other	Cost of materials and other	$	128.1	$	176.4	$	254.2	$	302.6			Cost of materials and other	$	150.6	$	177.7	$	404.8	$	480.3
Operating expenses (excluding depreciation and amortization)	Operating expenses (excluding depreciation and amortization)	$	29.0	$	21.0	$	53.7	$	39.1			Operating expenses (excluding depreciation and amortization)	$	33.0	$	25.9	$	86.7	$	65.0
EBITDA	EBITDA	$	90.9	$	62.6	$	182.3	$	126.8			EBITDA	$	96.5	$	87.3	$	278.8	$	214.1

Operating Information:	Operating Information:											Operating Information:
Gathering & Processing: (average bpd)	Gathering & Processing: (average bpd)											Gathering & Processing: (average bpd)
Lion Pipeline System:	Lion Pipeline System:											Lion Pipeline System:
Crude pipelines (non-gathered)	Crude pipelines (non-gathered)	61,260		84,699		62,131		78,818				Crude pipelines (non-gathered)	70,153		87,653		64,835		81,795
Refined products pipelines	Refined products pipelines	44,966		64,821		49,957		62,186				Refined products pipelines	63,991		65,761		54,686		63,391
SALA Gathering System	SALA Gathering System	13,041		17,961		13,509		17,064				SALA Gathering System	14,774		14,354		13,935		16,150
East Texas Crude Logistics System	East Texas Crude Logistics System	30,666		19,942		26,690		18,010				East Texas Crude Logistics System	36,298		23,960		29,928		20,015
Midland Gathering Assets (1)	Midland Gathering Assets (1)	221,876		101,236		221,993		100,783				Midland Gathering Assets (1)	248,443		121,304		230,907		107,699
Plains Connection System	Plains Connection System	255,035		154,086		247,856		158,025				Plains Connection System	250,550		184,254		248,763		166,864
Delaware Gathering Assets: (2)	Delaware Gathering Assets: (2)											Delaware Gathering Assets: (2)
Natural Gas Gathering and Processing (Mcfd) (3)	Natural Gas Gathering and Processing (Mcfd) (3)	73,309		51,292		74,008		51,292				Natural Gas Gathering and Processing (Mcfd) (3)	69,737		64,429		72,569		61,198
Crude Oil Gathering (average bpd)	Crude Oil Gathering (average bpd)	117,017		78,011		110,408		78,011				Crude Oil Gathering (average bpd)	111,973		86,483		110,935		84,497
Water Disposal and Recycling (average bpd)	Water Disposal and Recycling (average bpd)	127,195		57,625		107,848		57,625				Water Disposal and Recycling (average bpd)	99,158		69,411		104,920		66,043

Wholesale Marketing & Terminalling:	Wholesale Marketing & Terminalling:											Wholesale Marketing & Terminalling:
East Texas - Tyler refinery sales volumes (average bpd) (4)	East Texas - Tyler refinery sales volumes (average bpd) (4)	69,310		63,502		52,158		67,021				East Texas - Tyler refinery sales volumes (average bpd) (4)	69,178		65,396		57,894		66,473
Big Spring wholesale marketing throughputs (average bpd)	Big Spring wholesale marketing throughputs (average bpd)	75,164		78,634		76,763		77,100				Big Spring wholesale marketing throughputs (average bpd)	81,617		74,238		78,399		76,135
West Texas wholesale marketing throughputs (average bpd)	West Texas wholesale marketing throughputs (average bpd)	9,985		10,073		9,454		9,994				West Texas wholesale marketing throughputs (average bpd)	10,692		10,082		9,871		10,023
West Texas wholesale marketing margin per barrel	West Texas wholesale marketing margin per barrel	$	3.23	$	2.67	$	2.89	$	2.85			West Texas wholesale marketing margin per barrel	$	4.56	$	4.23	$	5.43	$	3.84
Terminalling throughputs (average bpd) (5)	Terminalling throughputs (average bpd) (5)	134,323		130,002		113,926		136,808				Terminalling throughputs (average bpd) (5)	121,430		142,003		116,455		138,558

(1) Formerly known as the Permian Gathering System. ~~Excludes volumes that are being temporarily transported via trucks while connectors are under construction.~~

(2) Formally known as 3 Bear, which was acquired June 1, 2022.

(3) Mcfd - average thousand cubic feet per day.

(4) Excludes jet fuel and petroleum coke.

(5) Consists of terminalling throughputs at our Tyler, Big Spring, Big Sandy and Mount Pleasant, Texas terminals, El Dorado and North Little Rock, Arkansas terminals and Memphis and Nashville, Tennessee terminals.

Logistics revenue is largely based on fixed-fee or tariff rates charged for throughput volumes running through our logistics network, where many of those volumes are contractually protected by minimum volume commitments ("MVCs"). To the extent that our logistics volumes are not subject to MVCs, our Logistics revenue may be negatively impacted in periods where are customers are experiencing economic pressures or reductions in demand for their products. Additionally, certain of our throughput arrangements contain deficiency credit provisions that may require us to defer excess MVC fees collected over actual throughputs to apply toward MVC deficiencies in future periods. With respect to our equity method investments in pipeline joint ventures, our earnings from those investments (which is based on our pro rata ownership percentage of the joint venture's recognized net income or loss) are directly impacted by the operations of those joint ventures. Items impacting the joint venture net income (loss) may include (but are not limited to) the following: long-term throughput contractual arrangements and related MVCs and, in some cases, deficiency credit provisions; the demand for walk-up nominations; applicable rates or tariffs; long-lived asset or other impairments assessed at the joint venture level; and pipeline releases or other contingent liabilities. With respect to our West Texas marketing activities, our profitability is dependent upon the cost of landed product versus the rack price of refined product sold. Our logistics segment is generally protected from commodity price risk because inventory is purchased and then immediately sold at the rack.


5254 \|

Management's Discussion and Analysis

Logistics Segment Operational Comparison of the Three and ~~Six~~Nine Months Ended ~~June~~September 30, 2023 versus the Three and ~~Six~~Nine Months Ended ~~June~~September 30, ~~2022.~~2022

Q2Q3 2023 vs. Q2Q3 2022

Net revenues decreased by ~~$19.8~~$18.2 million, or ~~7.4%~~6.2%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022, primarily driven by:

•decrease in revenue in our Delaware Gathering operations of $17.2 million primarily due to decrease in natural gas prices slightly offset by increases in water, crude oil and natural gas volumes; and

•decreased revenue of ~~$50.9~~$3.6 million in our West Texas marketing operations primarily driven by a decrease in the average sales prices per gallon of diesel, partially offset by an increase in the volumes sold:

◦the average sales prices per gallon of diesel sold decreased by $0.56 per gallon; and

◦the volumes of gasoline increased by 5.3 million, partially offset by a decrease of 1.2 million gallons of diesel sold.

These decreases were partially offset by the following:

•increase in throughput associated with Midland Gathering operations primarily due to new connections finalized during 2022; and

•increase in terminalling and marketing revenue primarily due to utilization and rate increases.

Net revenues included sales to our refining segment of $156.0 million and $126.1 million for the three months ended September 30, 2023 and September 30, 2022, respectively, and sales to our other segment of $0.4 million and $1.1 million for the three months September 30, 2023 and 2022, respectively. We eliminate this intercompany revenue in consolidation.

YTD 2023 vs. YTD 2022

Net revenues decreased by $1.1 million, or 0.1%, in the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022 primarily driven by the following:

•decreased revenue of $66.7 million in our West Texas marketing operations primarily driven by decreases in the average sales prices per gallon and the average volumes ~~sold:~~

◦~~the average sales prices per gallon~~ of ~~gasoline and diesel sold decreased by $0.93 per gallon and $1.53 per gallon, respectively; and~~

◦~~the average volumes of gasoline and diesel sold decreased by 0.6 million and 1.5 million gallons, respectively.~~

•~~partially offset by an increase in revenue as a result of our Delaware Gathering operations, which began in June 2022.~~

Net revenues included sales to our refining segment of $132.6 million and $123.8 million for the three months ended June 30, 2023 and June 30, 2022, respectively. We eliminate this intercompany revenue in consolidation.

~~YTD 2023 vs. YTD 2022~~

~~Revenues increased by $17.1 million, or 3.6%, in the six months ended June 30, 2023 compared to the six months ended June 30, 2022 primarily driven by the following:~~

•~~increase in revenue as a result of our Delaware Gathering operations, which began in June 2022;~~

•~~increase in volumes associated with Midland Gathering operations due to new connections finalized during 2022; and~~

•~~partially offset by decreased revenue in our West Texas marketing operations primarily driven by decreases in the average sales prices per gallon and the average volumes of gasoline and~~ diesel sold in our West Texas marketing operations:

◦the average sales prices per gallon of gasoline and diesel sold decreased by ~~$0.58~~$0.39 per gallon and ~~$0.79~~$0.71 per gallon, respectively; and

◦the ~~average~~ volumes of ~~gasoline and~~ diesel sold decreased by ~~3.4~~3.6 million gallons, ~~and 2.4~~partially offset by a 1.9 million increase in gallons ~~respectively.~~of gasoline sold.

These decreases were partially offset by the following:

•increase in revenue as a result of our Delaware Gathering operations, which began in June 2022; and

•increase in volumes associated with Midland Gathering operations primarily due to new connections finalized during 2022.

Revenues included sales to our refining segment of ~~$257.2~~$413.2 million and ~~$247.2~~$373.3 million for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively, and sales to our other segment of ~~$0.8~~$1.2 million and ~~$0.9~~$2.0 million for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively. We eliminate this intercompany revenue in consolidation.


5355 \|

Management's Discussion and Analysis

Cost of Materials and Other

Q2Q3 2023 vs. Q2Q3 2022

Cost of materials and other for the logistics segment decreased by ~~$48.3~~$27.1 million, or ~~27.4%~~15.3%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022. The decrease was primarily driven by the following:

•decrease of $16.9 million primarily as a result of a decrease in natural gas prices impacting our Delaware Gathering operations;

•decrease in costs of materials and other in our West Texas marketing operations primarily driven by decreases in the average cost per gallon, ~~and~~partially offset by an increase in the ~~average~~gasoline volumes ~~of gasoline and diesel~~ sold:

◦the average cost per gallon of gasoline and diesel sold decreased by ~~$0.32~~$0.41 per gallon and ~~$0.12~~$0.52 per gallon, respectively; and

◦the average volumes of ~~gallons and diesel sold decreased~~gasoline increased by ~~0.6~~5.3 million, ~~and 1.5 million gallons, respectively.~~

•partially offset by ~~increase in costs~~a decrease of ~~materials and other as a result~~1.2 million gallons of ~~our Delaware Gathering operations, which began in June 2022.~~diesel sold.

Our logistics segment purchased product from our refining segment of ~~$92.0~~$115.1 million and ~~$143.9~~$124.7 million for the three months ended ~~June~~September 30, 2023 and ~~June~~September 30, 2022, respectively. We eliminate these intercompany costs in consolidation.

YTD 2023 vs. YTD 2022

Cost of materials and other for the logistics segment decreased by ~~$48.4~~$75.5 million, or ~~16.0%~~15.7%, in the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022. This decrease was primarily driven by the following:

•decrease in costs of materials and other in our West Texas marketing operations primarily driven by decreases in the average cost per gallon and the average volumes of ~~gasoline and~~ diesel sold in our West Texas marketing operations:

◦the average cost per gallon of gasoline and diesel sold decreased by ~~$0.27~~$0.55 per gallon and ~~$0.11~~$0.74 per gallon, respectively; and

◦the ~~average~~ volumes of ~~gasoline and~~ diesel sold decreased by ~~3.4~~3.6 million gallons, ~~and 2.4~~partially offset by a 1.9 million increase in gallons ~~respectively.~~of gasoline sold.

•partially offset by increase in cost of materials and other as a result of our Delaware Gathering operations, which began in June 2022.

Our logistics segment purchased product from our refining segment of ~~$183.1~~$298.3 million and ~~$249.8~~$374.5 million for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively. We eliminate these intercompany costs in consolidation.


5456 \|

Management's Discussion and Analysis

Operating Expenses

Q2Q3 2023 vs. Q2Q3 2022

Operating expenses increased by ~~$8.0~~$7.1 million, or ~~38.1%~~27.4%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022, driven by ~~incremental~~an increase in variable expenses ~~associated with Delaware Gathering Acquisition~~due to higher throughput.

YTD 2023 vs. YTD 2022

Operating expenses increased by ~~$14.6~~$21.7 million, or ~~37.3%~~33.4%, in the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022, primarily driven by incremental expenses associated with Delaware Gathering Acquisition.

EBITDA

Q2Q3 2023 vs. Q2Q3 2022

EBITDA increased by ~~$28.3~~$9.2 million, or ~~45.2%~~10.5%, in the three months ended ~~June~~September 30, 2023 compared to the three months ended ~~June~~September 30, 2022, primarily driven by the following:

•higher throughput volumes; and

•~~incremental EBITDA from the Delaware Gathering Acquisition.~~rate increases..

YTD 2023 vs. YTD 2022

EBITDA increased by ~~$55.5~~$64.7 million, or ~~43.8%~~30.2%, in the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022, primarily driven by the following:

•higher throughput volumes; and

•incremental EBITDA from the Delaware Gathering Acquisition.


5557 \|

Management's Discussion and Analysis


Retail Segment

The tables below set forth certain information concerning our retail segment operations (gross sales $ in millions):


Selected Retail Financial and Operating Information	Selected Retail Financial and Operating Information									Selected Retail Financial and Operating Information
		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,		Nine Months Ended September 30,
		2023		2022		2023		2022					2023		2022		2023		2022
Revenues	Revenues	$	232.7	$	277.1	$	437.7	$	486.6			Revenues	$	236.5	$	253.1	$	674.2	$	739.7
Cost of materials and other	Cost of materials and other	188.5		233.8		$	358.5	$	406.8			Cost of materials and other	$	189.6	$	210.3	$	548.1	$	617.1
Operating expenses (excluding depreciation and amortization)	Operating expenses (excluding depreciation and amortization)	25.9		25.1		$	50.5	$	47.8			Operating expenses (excluding depreciation and amortization)	$	26.4	$	25.4	$	76.9	$	73.2

EBITDA	EBITDA	$	15.0	$	12.5	$	21.4	$	22.8			EBITDA	$	16.2	$	13.5	$	37.6	$	36.3


Operating Information	Operating Information													Operating Information
		Three Months Ended June 30,						Six Months Ended June 30,							Three Months Ended September 30,		Nine Months Ended September 30,
		2023			2022			2023			2022						2023			2022			2023			2022
Number of stores (end of period)	Number of stores (end of period)	247			248			247			248					Number of stores (end of period)	250			248			250			248
Average number of stores	Average number of stores	247			248			247			248					Average number of stores	250			248			250			248
Average number of fuel stores	Average number of fuel stores	242			243			242			243					Average number of fuel stores	245			243			245			243
Retail fuel sales	Retail fuel sales	$	148.4		$	193.6		$	279.5		$	333.5				Retail fuel sales	$	153.0		$	169.0		$	432.5		$	502.4
Retail fuel sales (thousands of gallons)	Retail fuel sales (thousands of gallons)	45,687			44,911			85,651			84,416					Retail fuel sales (thousands of gallons)	43,170			44,729			128,821			129,145
Average retail gallons per average number of stores (in thousands)	Average retail gallons per average number of stores (in thousands)	189			185			354			348					Average retail gallons per average number of stores (in thousands)	176			184			526			533
Average retail sales price per gallon sold	Average retail sales price per gallon sold	$	3.25		$	4.31		$	3.26		$	3.95				Average retail sales price per gallon sold	$	3.54		$	3.78		$	3.36		$	3.89
Retail fuel margin ($ per gallon) (1)	Retail fuel margin ($ per gallon) (1)	$	0.342		$	0.329		$	0.307		$	0.322				Retail fuel margin ($ per gallon) (1)	$	0.420		$	0.345		$	0.345		$	0.330
Merchandise sales (in millions)	Merchandise sales (in millions)	$	84.3		$	83.4		$	158.2		$	153.1				Merchandise sales (in millions)	$	83.5		$	84.2		$	241.7		$	237.3
Merchandise sales per average number of stores (in millions)	Merchandise sales per average number of stores (in millions)	$	0.3		$	0.3		$	0.6		$	0.6				Merchandise sales per average number of stores (in millions)	$	0.3		$	0.3		$	1.0		$	1.0
Merchandise margin %	Merchandise margin %	33.9		%	34.0		%	33.5		%	34.3		%			Merchandise margin %	34.4		%	32.6		%	33.8		%	33.7		%


Same-Store Comparison (2)	Same-Store Comparison (2)									Same-Store Comparison (2)
		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,					Nine Months Ended September 30,
		2023		2022		2023		2022				2023		2022			2023		2022

Change in same-store retail fuel gallons sold	Change in same-store retail fuel gallons sold	(1.5)	%	5.8	%	(1.6)	%	3.4	%	Change in same-store retail fuel gallons sold		(6.8)	%	7.4	%		(3.3)	%	4.7	%
Change in same-store merchandise sales	Change in same-store merchandise sales	0.1	%	0.1	%	2.4	%	(2.4)	%	Change in same-store merchandise sales		(1.9)	%	3.9	%		1.1	%	(0.3)	%

(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.

(2)Same-store comparisons include year-over-year changes in specified metrics for stores that were in service at both the beginning of the year and the end of the most recent year used in the comparison.

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.


5658 \|

Management's Discussion and Analysis

Retail Segment Operational Comparison of the Three and ~~Six~~Nine Months Ended ~~June~~September 30, 2023 versus the Three and ~~Six~~Nine Months Ended ~~June~~September 30, ~~2022.~~2022

Revenues

Q2Q3 2023 vs. Q2Q3 2022

Net revenues for the retail segment decreased by ~~$44.4~~$16.6 million, or ~~16.0%~~6.6%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022, primarily driven by the following:

•a decrease in total fuel sales which were ~~$148.4~~$153.0 million in the ~~second~~third quarter of 2023 compared to ~~$193.6~~$169.0 million in the ~~second~~third quarter of 2022, primarily attributable to a decrease of ~~$1.06~~$0.24 in average price charged per gallon ~~sold.~~sold; and

~~These decreases were partially offset by the following:~~

•~~an increase~~a decrease in merchandise sales to ~~$84.3~~$83.5 million in the ~~second~~third quarter of 2023 compared to ~~$83.4~~$84.2 million in the ~~second~~third quarter of 2022, primarily driven by the same-store sales ~~increase~~decrease of ~~0.1%~~1.9%.

YTD 2023 vs. YTD 2022

Revenues for the retail segment decreased by ~~$48.9~~$65.5 million, or ~~10.0%~~8.9%, for the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022, primarily driven by the following:

•a decrease in total fuel sales which were ~~$279.5~~$432.5 million for the ~~six~~nine months ended ~~June~~September 30, 2023 compared to ~~$333.5~~$502.4 million for the ~~six~~nine months ended ~~June~~September 30, 2022, primarily attributable to a ~~$0.69~~$0.53 decrease in average price charged per gallon sold.

These decreases were partially offset by the following:

•an increase in merchandise sales to ~~$158.2~~$241.7 million for the ~~six~~nine months ended ~~June~~September 30, 2023 compared to ~~$153.1~~$237.3 million for the ~~six~~nine months ended ~~June~~September 30, 2022, primarily driven by the same-store sales increase of ~~2.4%~~1.1%.


5759 \|

Management's Discussion and Analysis

Cost of Materials and Other

Q2Q3 2023 vs. Q2Q3 2022

Cost of materials and other for the retail segment decreased by ~~$45.3~~$20.7 million, or ~~19.4%~~9.8%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022, primarily driven by the following:

•a decrease in average cost per gallon of ~~$1.07,~~$0.31, or ~~26.9%~~9.0%, applied to fuel sales volumes that ~~increased~~decreased period over period.

Our retail segment purchased finished product from our refining segment of ~~$111.5~~$117.0 million and ~~$160.1~~$132.1 million for the three months ended ~~June~~September 30, 2023 and ~~June~~September 30, 2022, respectively, which is eliminated in consolidation.

YTD 2023 vs. YTD 2022

Cost of materials and other for the retail segment decreased by ~~$48.3~~$69.0 million, or ~~11.9%~~11.2%, for the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022, primarily driven by the following:

•a decrease in average cost per gallon of ~~$0.67,~~$0.55, or ~~18.5%~~15.4%.

Our retail segment purchased finished product from our refining segment of ~~$214.1~~$331.0 million and ~~$271.9~~$404.0 million for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, respectively. We eliminate this intercompany cost in consolidation.

Operating Expenses

Q2Q3 2023 vs. Q2Q3 2022

Retail segment operating expenses increased by ~~$0.8~~$1.0 million, or ~~3.2%~~3.9%, in the ~~second~~third quarter of 2023 compared to the ~~second~~third quarter of 2022, primarily due to driven by higher employee cost in 2023.

YTD 2023 vs. YTD 2022

Operating expenses for the retail segment increased by ~~$2.7~~$3.7 million, or ~~5.6%~~5.1%, for the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022 primarily driven by higher employee cost in 2023.

EBITDA

Q2Q3 2023 vs. Q2Q3 2022

EBITDA for the retail segment increased by ~~$2.5~~$2.7 million, or 20.0%, for the three months ended ~~June~~September 30, 2023 compared to the three months ended ~~June~~September 30, 2022, primarily driven by the following:

•an increase in average fuel margin of ~~$0.013~~$0.075 per gallon, ~~and an increase~~partially offset by a decrease in fuel sales volume; and

•~~a 1.0%~~an increase ~~in merchandise sales, partially offset by a decrease~~ in merchandise margin percentage of ~~0.1%.~~1.8%, partially offset by a 0.9% decrease in merchandise sales.

YTD 2023 vs. YTD 2022

EBITDA for the retail segment ~~decreased~~increased by ~~$1.4~~$1.3 million, or ~~6.1%~~3.6%, for the ~~six~~nine months ended ~~June~~September 30, 2023 compared to the ~~six~~nine months ended ~~June~~September 30, 2022, primarily driven by the following:

•~~a decrease~~an increase in average fuel margin of $0.015 per gallon, partially offset by ~~an increase~~a decrease in fuel sales volume; and

•a 1.8% increase in merchandise sales.

These increases were partially offset by the following:

•an increase in operating expenses due to higher employee costs.


60 \|

Management's Discussion and Analysis


5861 \|

Management's Discussion and Analysis

Liquidity and Capital Resources

Sources of Capital

Our primary sources of liquidity and capital resources are

•cash generated from our operating activities;

•borrowings under our debt facilities; and

•potential issuances of additional equity and debt securities.

At ~~June~~September 30, 2023 our total liquidity amounted to ~~$1.6~~$1.8 billion comprised primarily of ~~$787.5~~$906.9 million in unused credit commitments under our revolving credit facilities (as discussed in Note 9 of our condensed consolidated financial statements in Item 1. Financial Statements, of this Quarterly Report on Form 10-Q) and ~~$821.6~~$901.7 million in cash and cash equivalents. Historically, we have generated adequate cash from operations to fund ongoing working capital requirements, pay quarterly cash dividends and fund operational capital expenditures. On ~~August 4,~~November 1, 2023, our Board of Directors approved a quarterly cash dividend of ~~$0.235~~$0.24 per share of our common stock.

Other funding sources including borrowings under existing credit agreements, and issuance of equity and debt securities have been utilized to meet our funding requirements and support our growth capital projects and acquisitions. In addition, we have historically been able to source funding at terms that reflect market conditions, our financial position and our credit ratings and expect future funding sources to be at terms that are sustainable and profitable for the Company. However, there can be no assurances regarding the availability of future debt or equity financings or whether such financings can be made available on terms that are acceptable to us; any execution of such financing activities will be dependent on the contemporaneous availability of functioning debt or equity markets. Additionally, new debt financing activities will be subject to the satisfaction of any debt incurrence limitation covenants in our existing financing agreements. Our debt limitation covenants in our existing financing documents are usual and customary for credit agreements of our type and reflective of market conditions at the time of their execution. Additionally, our ability to satisfy working capital requirements, to service our debt obligations, to fund planned capital expenditures, or to pay dividends will depend upon future operating performance, which will be affected by prevailing economic conditions in the oil industry and other financial and business factors, including oil prices, some of which are beyond our control.

As of ~~June~~September 30, 2023, we believe we were in compliance with all of our debt maintenance covenants, where the most significant long-term obligation subject to such covenants was the Delek Term Loan Credit Facility (see further discussion in Note 9 of our condensed consolidated financial statements in Item 1. Financial Statements, of this Quarterly Report on Form 10-Q). Additionally, we were in compliance with incurrence covenants to the extent triggered during the quarter ended ~~June~~September 30, 2023. Failure to meet the incurrence covenants could impose certain incremental restrictions on our ability to incur new debt and also may limit whether and the extent to which we may pay dividends, as well as impose additional restrictions on our ability to repurchase our stock, make new investments and incur new liens (among others). Such restrictions would generally remain in place until such quarter that we return to compliance under the applicable incurrence based covenants. In the event that we are subject to these incremental restrictions, we believe that we have sufficient current and alternative sources of liquidity, including (but not limited to): available borrowings under our existing Delek Revolving Credit Facility, and for Delek Logistics, under its Delek Logistics Revolving Facility; the allowance to incur an additional $400.0 million of secured debt under the Delek Term Loan Credit Facility (see further discussion of these facilities in Note 9 of our condensed consolidated financial statements in Item 1. Financial Statements, of this Quarterly Report on Form 10-Q); as well as the possibility of obtaining other secured and unsecured debt, raising capital through equity issuance, or taking advantage of transactional financing opportunities such as sale-leasebacks or joint ventures, as otherwise contemplated and allowed under our incurrence covenants.

Cash Flows

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


Consolidated	Consolidated					Consolidated
		Six Months Ended June 30,					Nine Months Ended September 30,
		2023		2022					2023		2022
Cash Flow Data:	Cash Flow Data:							Cash Flow Data:
Operating activities	Operating activities	$	490.2	$	585.9			Operating activities	$	922.8	$	716.1
Investing activities	Investing activities	(279.9)		(720.9)				Investing activities	(338.6)		(819.9)
Financing activities	Financing activities	(230.0)		523.1				Financing activities	(523.8)		401.1
Net (decrease) increase		$	(19.7)	$	388.1
Net increase								Net increase	$	60.4	$	297.3

Cash Flows from Operating Activities

Net cash provided by operating activities was ~~$490.2~~$922.8 million for the ~~six~~nine months ended ~~June~~September 30, 2023, compared to ~~$585.9~~$716.1 million for the comparable period of 2022. ~~Decreases~~Increases were a result of ~~an increase in cash paid for debt interest of $84.5 million, partially offset by an increase in dividends received of $5.0 million. Additionally,~~ cash receipts from customers and cash payments to suppliers and for salaries ~~increased~~ resulting in a net ~~$18.8~~$297.8 million increase in cash provided by operating ~~activities.~~activities and an increase in dividends received of $9.5 million, partially offset by an increase in cash paid for debt interest of $118.8 million.


5962 \|

Management's Discussion and Analysis

Cash Flows from Investing Activities

Net cash used in investing activities was ~~$279.9~~$338.6 million for the ~~six~~nine months ended ~~June~~September 30, 2023, compared to ~~$720.9~~$819.9 million in the comparable period of 2022. The decrease in cash flows used in investing activities was primarily due to the ~~$621.7~~$625.4 million Delaware Gathering Acquisition in 2022 and a ~~$5.6~~$8.8 million increase in distributions from equity method investments, partially offset by a ~~$179.5~~$145.5 million increase in purchases of property, plant and equipment, substantially driven by maintenance projects associated with the Tyler turnaround, other refinery additions and various interconnects associated with Delek Logistics assets, and payments of ~~$9.0~~$11.0 million for equity interests investments.

Cash Flows from Financing Activities

Net cash used in financing activities was ~~$230.0~~$523.8 million for the ~~six~~nine months ended ~~June~~September 30, 2023, compared to cash provided of ~~$523.1~~$401.1 million in the comparable 2022 period. The decrease in cash provided was primarily due to net payments on long-term revolvers and term debt of ~~$248.0~~$423.7 million during the ~~six~~nine months ended ~~June~~September 30, 2023, compared to net proceeds of ~~$595.5~~$509.3 million in the comparable 2022 period, net payments from product financing arrangements of $14.4 million for the nine months ended September 30, 2023 compared to net proceeds of $40.0 million in the comparable 2022 period, an increase in dividend payments of ~~$29.7~~$16.6 million ~~made during the six months ended June 30, 2023~~ and proceeds received of $16.4 million in the comparable 2022 period for the sale of Delek Logistics common limited partner units.

These decreases in cash flows were partially offset by a decrease in share repurchases of ~~$23.6~~$38.6 million combined with the impact of the following: net proceeds from product financing arrangements of $52.8 million for the six months ended June 30, 2023 compared to net payments $2.8 million in the comparable 2022 period, and the receipt of settlement proceeds of $58.0 million during the first quarter of 2023 associated with the termination of the J. Aron Supply & Offtake Agreements and origination of the Citi Inventory Intermediation ~~Agreement.~~Agreement (as defined in Note 8 of the condensed consolidated financial statements in Item 1. Financial Statements).

Cash Position and Indebtedness

As of ~~June~~September 30, 2023, our total cash and cash equivalents were ~~$821.6~~$901.7 million and we had total long-term indebtedness of approximately ~~$2,810.9~~$2,638.0 million. The total long-term indebtedness is net of deferred financing costs and debt discount of ~~$62.9~~$60.1 million. Additionally, we had letters of credit issued of approximately ~~$251.5~~$301.6 million. Total unused credit commitments or borrowing base availability, as applicable, under our revolving credit facilities was approximately ~~$787.5~~$906.9 million. The decrease of ~~$246.7~~$422.4 million in total long-term indebtedness as of ~~June~~September 30, 2023 compared to December 31, 2022 resulted primarily from a decrease in net borrowings under the Delek Revolving Credit Facility and the United Community Bank Revolver, partially offset by an increase in net borrowings under the Delek Logistics Revolving Facility. As of ~~June~~September 30, 2023, our total long-term indebtedness (as defined in Note 9 of the condensed consolidated financial statements in Item 1. Financial Statements) consisted of the following:

•aggregate principal of ~~$150.0~~$0.3 million under the Delek Revolving Credit Facility (maturity of October 26, 2027 and average borrowing rate of ~~6.45%~~6.68%);

•aggregate principal of ~~$945.3~~$942.9 million under the Delek Term Loan Credit Facility (maturity of November 19, 2029 and effective interest of ~~9.95%~~10.16%);

•aggregate principal of ~~$811.0~~$811.2 million under the Delek Logistics Revolving Facility, (maturity of October 13, 2027 (which will accelerate to 180 days prior to the stated maturity date of the Delek Logistics 2025 Notes if any of the Delek Logistics 2025 Notes remain outstanding on that date) and average borrowing rate of ~~7.95%~~8.45%);

•aggregate principal of ~~$292.5~~$288.7 million under the Delek Logistics Term Loan Facility (maturity of ~~October 13, 2024~~April 15, 2025 (which will accelerate to 180 days prior to the stated maturity date of the Delek Logistics 2025 Notes if any of the Delek Logistics 2025 Notes remain outstanding on that date) and average borrowing rate of ~~8.41%~~8.92%);

•aggregate principal of $250.0 million under the Delek Logistics 2025 Notes (due in 2025, with effective interest rate of ~~7.17%~~7.18%);

•aggregate principal of $400.0 million under the Delek Logistics 2028 Notes (due in 2028, with effective interest rate of 7.39%); and

•aggregate principal of ~~$25.0~~$5.0 million under the United Community Bank Revolver (maturity of June 30, 2024 and average borrowing rate of ~~7.50%~~7.75%).

On November 6, 2023, Delek Logistics entered into a First Amendment, a Second Amendment and a Third Amendment to the Delek Logistics Credit Facility (together, the “Amendments”). The Amendments, (i) increased the Delek Logistics Revolving Credit Facility's Revolving Credit Commitments (as defined in the Delek Logistics Credit Facility) by an amount equal to $150.0 million to provide for an aggregate Revolving Credit Commitments amount of $1.050 billion, (ii) increased Delek Logistics' ability to incur certain indebtedness and (iii) extended the Delek Logistics Term Loan maturity date from October 13, 2024, to the earlier of (i) April 15, 2025, and (ii) six months prior to the earliest maturity date of any outstanding Permitted Note Indebtedness (as defined in the Delek Logistics Credit Facility).

See Note 9 to our accompanying condensed consolidated financial statements in Item 1. Financial Statements, of this Quarterly Report on Form 10-Q for additional information about our separate debt and credit facilities.


63 \|

Management's Discussion and Analysis

Additionally, we utilize other financing arrangements to finance operating assets and/or, from time to time, to monetize other assets that may not be needed in the near term, when internal cost of capital and other criteria are met. Such arrangements include our inventory intermediation arrangement, which finances a significant portion of our first-in, first-out inventory at the refineries and, from time to time, RINs or other non-inventory product financing liabilities. On ~~June 21,~~September 18, 2023, DKTS entered into a letter agreement to the Inventory Intermediation Agreement with Citi to temporarily increase its letter of credit issued to Citi by ~~$100.0~~$180.0 million which ~~will allow~~allowed DKTS to defer payments of certain obligations under the Inventory Intermediation Agreement until ~~July~~October 2023. These deferred obligations ~~will be~~were subject to applicable interest charges. Our inventory intermediation obligation with Citi was ~~$453.4~~$502.2 million at ~~June~~September 30, 2023, none of which iswas current. See Note 8 of the accompanying condensed consolidated financial statements in Item 1. Financial Statements, of this Quarterly Report on Form 10-Q for additional information about our inventory intermediation agreement. Our product financing liabilities consisted primarily of RIN financings as of ~~June~~September 30, 2023, and totaled ~~$322.4~~$260.8 million, all of which is due in the next 12 months. See further description of these types of arrangements in the Environmental Credits and Related Regulatory Obligations accounting policy disclosed in Note 2 to our accompanying consolidated financial statements included in Item 8. Financial Statements and Supplementary Data, of our December 31, 2022 Annual Report on Form 10-K. For both arrangements and the related commitments, see also our "Cash Requirements" section below.

Debt Ratings

We receive debt ratings from the major ratings agencies in the U.S. In determining our debt ratings, the agencies consider a number of qualitative and quantitative items including, but not limited to, commodity pricing levels, our liquidity, asset quality, reserve mix, debt levels and seniorities, cost structure, planned asset sales and production growth opportunities.


~~60 \|~~

~~Management's Discussion and Analysis~~

There are no "rating triggers" in any of our contractual debt obligations that would accelerate scheduled maturities should our debt rating fall below a specified level. However, a downgrade could adversely impact our interest rate on new credit facility borrowings and the ability to economically access debt markets in the future. Additionally, any rating downgrades may increase the likelihood of us having to post additional letters of credit or cash collateral under certain contractual arrangements.

Capital Spending

A key component of our long-term strategy is our capital expenditure program. The following table summarizes our actual capital expenditures for the ~~six~~nine months ended ~~June~~September 30, 2023, by segment, as well as planned capital expenditures for the full year 2023 by operating segment and major category (in millions):

2023 Forecast Six Months Ended June 30, 2023 Actual
Refining
Regulatory $ 21.5 $ 2.7
Sustaining maintenance, including turnaround activities 174.0 174.3
Growth projects 6.3 0.1
Refining segment total 201.8 177.1
Logistics
Regulatory 13.0 1.2
Sustaining maintenance 2.2 1.3
Growth projects 66.1 53.0
Logistics segment total 81.3 55.5
Retail
Regulatory — —
Sustaining maintenance 26.9 6.2
Growth projects 4.2 1.8
Retail segment total 31.1 8.0
Corporate and Other
Regulatory 2.1 1.5
Sustaining maintenance 32.1 9.5
Growth projects 2.1 1.7
Other total 36.3 12.7
Total capital spending $ 350.5 $ 253.3




	Nine Months Ended September 30, 2023 Actual
Refining
Regulatory	$	9.8
Sustaining maintenance, including turnaround activities	187.2
Growth projects	0.3
Refining segment total	197.3
Logistics
Regulatory	2.1
Sustaining maintenance	3.8
Growth projects	62.7
Logistics segment total	68.6
Retail
Regulatory	—
Sustaining maintenance	12.5
Growth projects	3.5
Retail segment total	16.0
Corporate and Other
Regulatory	1.6
Sustaining maintenance	16.0
Growth projects	2.1
Other total	19.7
Total capital spending	$	301.6

The 2023 full year capital expenditure forecast is expected to be between $380.0 million to $390.0 million. In addition, we expect to receive estimated insurance and other proceeds of $20.0 million in 2023 that are not reflected in the full year forecast.


64 \|

Management's Discussion and Analysis

The amount of our capital expenditure ~~budget~~forecast is subject to change due to unanticipated increases in the cost, scope and completion time for our capital projects and subject to the changes and uncertainties discussed under the 'Forward-Looking Statements' section of Item 2. Management Discussion and Analysis, of this Quarterly Report on Form 10-Q. For further information, please refer to our discussion in Item 1A. Risk Factors, of our December 31, 2022 Annual Report on Form 10-K.


~~61 \|~~

~~Management's Discussion and Analysis~~

Cash Requirements

Long-Term Cash Requirements Under Contractual Obligations

Information regarding our known cash requirements under contractual obligations of the types described below as of ~~June~~September 30, 2023, is set forth in the following table (in millions):


		Payments Due by Period											Payments Due by Period
		<1 Year		1-3 Years		3-5 Years		>5 Years		Total			<1 Year		1-3 Years		3-5 Years		>5 Years		Total
Long-term debt and notes payable obligations	Long-term debt and notes payable obligations	$	49.5	$	546.5	$	1,380.0	$	897.8	$	2,873.8	Long-term debt and notes payable obligations	$	29.5	$	542.7	$	1,230.5	$	895.4	$	2,698.1
Interest (1)	Interest (1)	228.7		401.2		312.9		124.3		1,067.1		Interest (1)	224.5		387.8		291.6		106.3		1,010.2
Operating lease commitments (2)	Operating lease commitments (2)	57.0		75.8		35.4		20.6		188.8		Operating lease commitments (2)	50.5		75.6		33.8		18.7		178.6
Purchase commitments (3)	Purchase commitments (3)	562.3		—		—		—		562.3		Purchase commitments (3)	476.0		—		—		—		476.0
Product financing agreements (4)	Product financing agreements (4)	322.4		—		—		—		322.4		Product financing agreements (4)	260.8		—		—		—		260.8
Transportation agreements (5)	Transportation agreements (5)	215.0		420.2		292.8		364.1		1,292.1		Transportation agreements (5)	207.6		407.5		257.6		339.0		1,211.7
Inventory intermediation obligation (6)	Inventory intermediation obligation (6)	41.6		474.4		—		—		516.0		Inventory intermediation obligation (6)	46.7		514.0		—		—		560.7
Total	Total	$	1,476.5	$	1,918.1	$	2,021.1	$	1,406.8	$	6,822.5	Total	$	1,295.6	$	1,927.6	$	1,813.5	$	1,359.4	$	6,396.1

(1) Expected interest payments on debt outstanding at ~~June~~September 30, 2023. Floating interest rate debt is calculated using ~~June~~September 30, 2023 rates. For additional information, see Note 9 to the condensed consolidated financial statements in Item 1. Financial Statements, of this Quarterly Report on Form 10-Q.

(2) Amounts reflect future estimated lease payments under operating leases having remaining non-cancelable terms in excess of one year as of ~~June~~September 30, 2023.

(3) We have purchase commitments to secure certain quantities of crude oil, finished product and other resources used in production at both fixed and market prices. We have estimated future payments under the market-based agreements using current market rates. Excludes purchase commitments in buy-sell transactions which have matching notional amounts with the same counterparty and are generally net settled in exchanges.

(4) Balances consist of obligations under RINs product financing arrangements, as described in Note 12 to the condensed consolidated financial statements in Item 1. Financial Statements, of this Quarterly Report on Form 10-Q and further discussed in the ''Environmental Credits and Related Regulatory Obligations' accounting policy included in Note 2 to our consolidated financial statements in Item 8. Financial Statements and Supplementary Data, of our December 31, 2022 Annual Report on Form 10-K.

(5) Balances consist of contractual obligations under agreements with third parties (not including Delek Logistics) for the transportation of crude oil to our refineries.

(6) Balances consist of contractual obligations under the Citi Inventory Intermediation Agreement, including principal obligation for the Baseline Volume Step-Out Liability and other recurring fees. For additional information, see Note 8 to the condensed consolidated financial statements in Item 1. Financial Statements, of this Quarterly Report on Form 10-Q.

Other Cash Requirements

Our material short-term cash requirements under contractual obligations are presented above, and we expect to fund the majority of those requirements with cash flows from operations. Our other cash requirements consisted of operating activities and capital expenditures. Operating activities include cash outflows related to payments to suppliers for crude and other inventories (which are largely reflected in our contractual purchase commitments in the table above) and payments for salaries and other employee related costs. Cash outlays in 2023 included incentive compensation payments that were earned and accrued in 2022. In line with our long-term sustainable strategy, future cash requirements will include initiatives to build on our long-term sustainable business model, ESG initiatives and sum of the parts initiatives.

Refer to the cash flow section for our operating activities spend during the ~~six~~nine months ended ~~June~~September 30, 2023. While many of the expenses related to the operating activities are variable in nature, some of the expenditures can be somewhat fixed in the short-term due to forward planning on our level of activity.

Refer to the 'Capital Spending' section for our capital expenditures for ~~six~~nine months ended ~~June~~September 30, 2023 and our anticipated cash requirements for planned capital expenditures for the full year 2023.

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, filed on March 1, 2023.


6265 \|

Management's Discussion and Analysis

Price Risk Management Activities

At times, we enter into the following instruments/transactions in order to manage our market-indexed pricing risk: commodity derivative contracts which we use 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; and future commitments to purchase or sell RINs at fixed prices and quantities, which are used to manage the costs associated with our RINs obligations and meet the definition of derivative instruments under Accounting Standards Codification ("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, excluding our trading derivative contracts (which are presented separately below), as of ~~June~~September 30, 2023 ($ in millions):


		Total Outstanding			Notional Contract Volume by Year of Maturity		Total Outstanding	Notional Contract Volume by Year of Maturity
Contract Description	Contract Description	Fair Value		Notional Contract Volume	2023	2024			Contract Description	Fair Value		Notional Contract Volume	2023	2024
Contracts not designated as hedging instruments:	Contracts not designated as hedging instruments:								Contracts not designated as hedging instruments:
Crude oil price swaps - long (1)	Crude oil price swaps - long (1)	$	(4.0)	69,847,000	50,773,000	19,074,000			Crude oil price swaps - long (1)	$	19.6	38,960,000	17,184,000	21,776,000
Crude oil price swaps - short (1)	Crude oil price swaps - short (1)	9.3		73,253,000	54,908,000	18,345,000			Crude oil price swaps - short (1)	(29.0)		37,469,000	17,059,000	20,410,000
Inventory, refined product and crack spread swaps - long (1)	Inventory, refined product and crack spread swaps - long (1)	2.1		3,386,000	3,386,000	—			Inventory, refined product and crack spread swaps - long (1)	5.6		4,585,000	4,585,000	—
Inventory, refined product and crack spread swaps - short (1)	Inventory, refined product and crack spread swaps - short (1)	(0.4)		4,862,000	4,862,000	—			Inventory, refined product and crack spread swaps - short (1)	(6.7)		5,194,000	5,194,000	—
Natural gas swaps - long (3)	Natural gas swaps - long (3)	(0.1)		4,160,000	4,160,000	—			Natural gas swaps - long (3)	(0.2)		1,007,500	1,007,500	—
Natural gas swaps - short (3)	Natural gas swaps - short (3)	(0.3)		2,627,500	2,627,500	—			Natural gas swaps - short (3)	0.1		697,500	697,500	—
RINs commitment contracts - long (2)	RINs commitment contracts - long (2)	(0.1)		70,800,000	70,800,000	—			RINs commitment contracts - long (2)	(3.3)		12,000,000	12,000,000	—
RINs commitment contracts - short (2)	RINs commitment contracts - short (2)	(0.8)		10,300,000	10,300,000	—			RINs commitment contracts - short (2)	2.1		5,000,000	5,000,000	—
Total	Total	$	5.7						Total	$	(11.8)

(1) Volume in barrels.

(2) Volume in RINs.

(3) Volume in MMBtu.

Interest Rate Risk

We have market exposure to changes in interest rates relating to our outstanding floating rate borrowings, which totaled approximately ~~$2,223.8~~$2,048.1 million as of ~~June~~September 30, 2023. The annualized impact of a hypothetical one percent change in interest rates on our floating rate debt outstanding as of ~~June~~September 30, 2023 would be to change interest expense by approximately ~~$22.2~~$20.5 million.

We also have interest rate exposure in connection with our Inventory Intermediation Agreement under which we pay a time value of money charge based on SOFR.

Inflation

Inflationary factors, such as increases in the costs of our inputs, operating expenses, and interest rates may adversely affect our operating results. ~~During the~~ ~~six months ended~~ 2023, our results of operations were negatively affected by higher labor costs and supply chain disruptions, the uncertain economic environment, and macroeconomic and geopolitical events and trends. We expect these cost pressures and supply chain challenges to continue through 2023. In addition, current or future governmental policies may increase or decrease the risk of inflation, which could further increase costs and may have an adverse effect on our ability to maintain current levels of gross margin and operating expenses as a percentage of sales if the prices at which we are able to sell our products and services do not increase in line with increases in costs.


6366 \|

Management's Discussion and Analysis

Commodity Derivatives Trading Activities

We enter into active trading positions in a variety of commodity derivatives, which include forward physical contracts, swap contracts, and futures contracts. These 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 are classified as held for trading and are recognized at fair value with changes in fair value recognized in the income statement.

The following table sets forth information relating to trading commodity derivative contracts as of ~~June~~September 30, 2023 ($ in millions):


		Total Outstanding			Notional Contract Volume by Year of Maturity	Total Outstanding	Notional Contract Volume by Year of Maturity
Contract Description	Contract Description	Fair Value		Notional Contract Volume	2023			Contract Description	Fair Value		Notional Contract Volume	2023
Crude forward contracts - long(1)	Crude forward contracts - long(1)	$	46.5	629,287	629,287			Crude forward contracts - long(1)	$	26.9	308,889	308,889
Crude forward contracts - short(1)	Crude forward contracts - short(1)	(46.5)		629,287	629,287			Crude forward contracts - short(1)	(34.6)		390,696	390,696
Total	Total	$	—					Total	$	(7.7)

(1) Volume in barrels.


6467 \|

Controls and Procedures

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 Exchange Act is accumulated and appropriately communicated to management. 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.

There have been no changes in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) that occurred during the ~~second~~third quarter of 2023 that have materially affected or are reasonably likely to materially affect our internal control over financial reporting.


6568 \|

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. See Note 12 to our accompanying condensed consolidated financial statements, which is incorporated by reference in this Item 1, for additional information. Aside from the disclosure updated in Note 12, there have been no material developments to the proceedings previously reported in our Annual Report on Form 10-K filed on March 1, 2023.

ITEM 1A. RISK FACTORS

There were no material changes during the ~~six~~nine months ended ~~June~~September 30, 2023 to the risk factors identified in the Company’s fiscal 2022 Annual Report on Form 10-K.

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

The following table sets forth information with respect to the purchase of shares of our common stock made during the three months ended ~~June~~September 30, 2023 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 ~~June~~September 30, 2023).

(a) (b) (c) (d)
Period Total Number of Shares Purchased Average Price Paid per Share
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs (1)
Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs
April 1 - April 30, 2023 1,184,067 $ 22.93 1,184,067 $ 242,853,396
May 1 - May 31, 2023 611,268 $ 20.94 611,268 $ 230,054,219
June 1 - June 30, 2023 — $ — — $ 230,054,219
Total 1,795,335 $ 22.25 1,795,335 N/A


	(a)	(b)		(c)	(d)
Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs (1)	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs








July 1 - July 31, 2023	727,196	$	24.75	727,196	$	212,054,409
August 1 - August 31, 2023	254,494	$	27.51	254,494	205,054,230
September 1 - September 30, 2023	—	$	—	—	205,054,230
Total	981,690	$	25.47	981,690	N/A

(1) See further discussion in Note 17 to our Condensed Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

ITEM 5. OTHER INFORMATION

Rule 10b5-1 Trading Plans

During the quarter ended ~~June~~September 30, 2023, none of ~~the Company’s~~our directors or officers (as defined in Rule ~~16a-1(f))~~16a-1 under the Exchange Act) adopted, modified or terminated ~~any contract, instruction~~a "Rule 10b5-1 trading arrangement" or ~~written plan~~"non-Rule 105b-1 trading arrangement" (as those terms are defined in Item 408 of Regulation S-K), except as follows:

On August 10, 2023, Reuven Spiegel, Executive Vice President & Chief Financial Officer, adopted a Rule 10b5-1 trading arrangement for the ~~purchase or~~ sale of ~~Company securities that was intended~~up to ~~satisfy the affirmative defense conditions~~13,500 shares of our common stock, subject to certain conditions. The arrangement's expiration date is April 11, 2025.

On August 11, 2023, Robert G. Wright, Senior Vice President, Chief Accounting Officer, adopted a Rule ~~10b5-1(c) or any “non-Rule~~ 10b5-1 trading ~~arrangement.”~~arrangement for the sale of up to 7,735 shares of our common stock, subject to certain conditions. The arrangement's expiration date is November 1, 2024.

On September 6, 2023, Laurie Tolson, a member of our Board of Directors, adopted a Rule 10b5-1 trading arrangement for the sale of up to 2,414 shares of common stock subject to certain conditions. The arrangement's expiration date is June 14, 2024.

On September 13, 2023, Ezra Uzi Yemin, Executive Chairman of our Board of Directors, adopted a Rule 10b5-1 trading arrangement for the sale of up to 360,000 shares of our common stock, subject to certain conditions. The arrangement's expiration date is December 13, 2024. On September 27, 2023, Mr. Yemin also terminated a Rule 10b5-1 trading arrangement for the sale of up to 13,066 shares of our common stock, subject to certain conditions, that he had entered into on June 3, 2022, with an original expiration date of July 3, 2024.


69 \|

Other Information

Intercompany Note

The Company entered into a certain Promissory Note (the “Note”) with Delek Logistics and certain of its subsidiaries, as guarantors, dated November 6, 2023. The Note provides for revolving borrowings with aggregate commitments of $70,000,000, comprised of a (i) $55,000,000 senior tranche and a (ii) $15,000,000 subordinated tranche (the “Subordinated Tranche”), with the initial borrowings under the Subordinated Tranche conditioned upon the Company and Delek Logistics reaching an agreement with Fifth Third Bank, National Association, as administrative agent under the DKL Credit Facility, on subordination provisions and other material terms related to the Subordinated Tranche. The Note will bear interest at Term SOFR (as defined in the Note) plus 3.00%. The Note proceeds will be used for Delek Logistics' working capital purposes and other general corporate purposes. The Note will mature on June 30, 2028. The Note contains certain affirmative covenants, mandatory prepayments and events of default that the Company considers to be customary for an arrangement of this sort. The obligations under the Note are unsecured.

The foregoing description of the Note is not complete and is qualified in its entirety by reference to the full text of the Note, a copy of which is filed as Exhibit 10.2 to this Quarterly Report on Form 10-Q and is incorporated herein by reference.


70 \|

ITEM 6. EXHIBITS


~~66 \|~~


Exhibit No.		Description

10.1	#	Letter Agreement, dated as of ~~April 6,~~September 18, 2023, by and between Citigroup Energy, Inc. and DK Trading & Supply, LLC.

10.2	#	~~Letter Agreement,~~Promissory Note dated ~~as of June 21,~~November 6, 2023 by and ~~between Citigroup Energy, Inc. and DK Trading & Supply, LLC.~~

~~10.3~~	*	~~Fifth Amendment to~~among Delek US Holdings, Inc. ~~2016 Long-Term Incentive Plan (incorporated by reference to Exhibit 10.1 to the Company's Form 8-K filed on May 8, 2023).~~and Delek Logistics Partners, LP.

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 ~~June~~September 30, 2023, formatted in Inline XBRL (eXtensible Business Reporting Language): (i) Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2023 and ~~June~~September 30, 2022 (Unaudited), (ii) Condensed Consolidated Statements of Income for the three and ~~six~~nine months ended ~~June~~September 30, 2023 and 2022 (Unaudited), (iii) Condensed Consolidated Statements of Comprehensive Income for the three and ~~six~~nine months ended ~~June~~September 30, 2023 and 2022 (Unaudited), (iv) Condensed Consolidated Statements of Changes in Stockholders' Equity for the three and ~~six~~nine months ended ~~June~~September 30, 2023 and 2022 (Unaudited), (v) Condensed Consolidated Statements of Cash Flows for the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022 (Unaudited), and (vi) Notes to Condensed Consolidated Financial Statements (Unaudited).

104		The cover page from Delek US Holdings, Inc.'s Quarterly Report on Form 10-Q for the quarter ended ~~June~~September 30, 2023, has been formatted in Inline XBRL.



*						Management contract or compensatory plan or arrangement.
#						Filed herewith
##						Furnished herewith


6771 \|

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/ Avigal Soreq
			Avigal Soreq
			President and Chief Executive Officer (Principal Executive Officer)

By:			/s/ Reuven Spiegel
			Reuven Spiegel
			Executive Vice President and Chief Financial Officer (Principal Financial Officer)

By:			/s/ Robert Wright
			Robert Wright
			Senior Vice President and Chief Accounting Officer (Principal Accounting Officer)

Dated: ~~August~~November 8, 2023


6872 \|





































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 Statement s of Changes in Stockholders' Equity						6
Condensed Consolidated Statements of Cash Flows						8
Notes to Condensed Consolidated Financial Statements						9
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations						2829
Item 3. Quantitative and Qualitative Disclosures about Market Risk						6265
Item 4. Controls and Procedures						6568

PART II. OTHER INFORMATION
Item 1. Legal Proceedings						6669
Item 1A. Risk Factors						6669
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds						6669
Item 5. Other Information						6669
Item 6. Exhibits						6671
Signatures						6872


Inter-refinery Sales
	Three Months Ended June 30,		Six Months Ended June 30,
(in barrels per day)	2023	2022	2023	2022


El Dorado refined product sales to other Delek refineries	—	1,531	—	1,201
Big Spring refined product sales to other Delek refineries	—	470	—	554
Krotz Springs refined product sales to other Delek refineries	—	1,061	—	783




	2023 Forecast		Six Months Ended June 30, 2023 Actual
Refining
Regulatory	$	21.5	$	2.7
Sustaining maintenance, including turnaround activities	174.0		174.3
Growth projects	6.3		0.1
Refining segment total	201.8		177.1
Logistics
Regulatory	13.0		1.2
Sustaining maintenance	2.2		1.3
Growth projects	66.1		53.0
Logistics segment total	81.3		55.5
Retail
Regulatory	—		—
Sustaining maintenance	26.9		6.2
Growth projects	4.2		1.8
Retail segment total	31.1		8.0
Corporate and Other
Regulatory	2.1		1.5
Sustaining maintenance	32.1		9.5
Growth projects	2.1		1.7
Other total	36.3		12.7
Total capital spending	$	350.5	$	253.3