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 30, 2020March 31, 2021
or
☐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
dk-20210331_g1.jpg
35-2581557
(State or other jurisdiction of incorporation or organization)(I.R.S. Employer Identification No.)
7102 Commerce WayBrentwoodTennessee37027
(Address of principal executive offices)(Zip Code)
(615) (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 ClassTrading SymbolName of Each Exchange on Which Registered
Common Stock, par value $0.01DKDKNew York Stock Exchange
At July 31, 2020,April 30, 2021, there were 73,657,43773,875,724 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 30, 2020

March 31, 2021
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements (unaudited)
3
Condensed Consolidated Balance Sheets
3
Condensed Consolidated Statements of Income
4
Condensed Consolidated Statements of Comprehensive Income
5
Condensed Consolidated Statements of Changes in Stockholders' Equity
6
Condensed Consolidated Statements of Cash Flows
108
Notes to Condensed Consolidated Financial Statements
119
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
3732
Item 3. Quantitative and Qualitative Disclosures about Market Risk
7663
Item 4. Controls and Procedures
7864
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
7966
Item 1A. Risk Factors
7966
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
80
Item 5. Other Information
8166
Item 6. Exhibits
8267
Signatures
8368

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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, 2020 December 31, 2019March 31, 2021December 31, 2020
ASSETS    ASSETS  
Current assets:    Current assets:  
Cash and cash equivalents $849.0
 $955.3
Cash and cash equivalents$793.5 $787.5 
Accounts receivable, net 480.4
 792.6
Accounts receivable, net720.2 527.9 
Inventories, net of inventory valuation reserves 653.5
 946.7
Inventories, net of inventory valuation reserves1,034.6 727.7 
Other current assets 390.0
 268.7
Other current assets358.2 256.4 
Total current assets 2,372.9
 2,963.3
Total current assets2,906.5 2,299.5 
Property, plant and equipment:    Property, plant and equipment:  
Property, plant and equipment 3,514.9
 3,362.8
Property, plant and equipment3,580.7 3,519.5 
Less: accumulated depreciation (1,031.5) (934.5)Less: accumulated depreciation(1,212.9)(1,152.3)
Property, plant and equipment, net 2,483.4
 2,428.3
Property, plant and equipment, net2,367.8 2,367.2 
Operating lease right-of-use assets 183.9
 183.6
Operating lease right-of-use assets174.1 182.0 
Goodwill 855.7
 855.7
Goodwill729.7 729.7 
Other intangibles, net 110.0
 110.3
Other intangibles, net106.9 107.8 
Equity method investments 367.3
 407.3
Equity method investments360.2 363.6 
Other non-current assets 64.4
 67.8
Other non-current assets98.8 84.3 
Total assets $6,437.6
 $7,016.3
Total assets$6,744.0 $6,134.1 
LIABILITIES AND STOCKHOLDERS’ EQUITY    LIABILITIES AND STOCKHOLDERS’ EQUITY  
Current liabilities:    Current liabilities:  
Accounts payable $1,004.2
 $1,599.7
Accounts payable$1,353.6 $1,144.0 
Current portion of long-term debt 33.4
 36.4
Current portion of long-term debt13.4 33.4 
Obligation under Supply and Offtake Agreements 99.0
 332.5
Obligation under Supply and Offtake Agreements125.0 129.2 
Current portion of operating lease liabilities 43.4
 40.5
Current portion of operating lease liabilities47.5 50.2 
Accrued expenses and other current liabilities 409.3
 346.8
Accrued expenses and other current liabilities961.8 546.4 
Total current liabilities 1,589.3
 2,355.9
Total current liabilities2,501.3 1,903.2 
Non-current liabilities:    Non-current liabilities:  
Long-term debt, net of current portion 2,421.5
 2,030.7
Long-term debt, net of current portion2,354.4 2,315.0 
Obligation under Supply and Offtake Agreements 215.0
 144.8
Obligation under Supply and Offtake Agreements287.1 224.9 
Environmental liabilities, net of current portion 106.3
 137.9
Environmental liabilities, net of current portion107.0 107.4 
Asset retirement obligations 36.8
 68.6
Asset retirement obligations37.8 37.5 
Deferred tax liabilities 335.4
 267.9
Deferred tax liabilities258.5 255.5 
Operating lease liabilities, net of current portion 140.2
 144.3
Operating lease liabilities, net of current portion125.9 131.8 
Other non-current liabilities 33.8
 30.9
Other non-current liabilities43.1 33.7 
Total non-current liabilities 3,289.0
 2,825.1
Total non-current liabilities3,213.8 3,105.8 
Stockholders’ equity:    Stockholders’ equity:  
Preferred stock, $0.01 par value, 11,000,000 shares and 10,000,000 shares authorized at June 30,2020 and December 31, 2019, respectively, no shares issued and outstanding —
 —
Common stock, $0.01 par value, 110,000,000 shares authorized, 91,232,964 shares and 90,987,025 shares issued at June 30, 2020 and December 31, 2019, respectively 0.9
 0.9
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 0 shares issued and outstandingPreferred stock, $0.01 par value, 10,000,000 shares authorized, 0 shares issued and outstanding0 0 
Common stock, $0.01 par value, 110,000,000 shares authorized, 91,450,724 shares and 91,356,868 shares issued at March 31, 2021 and December 31, 2020, respectivelyCommon stock, $0.01 par value, 110,000,000 shares authorized, 91,450,724 shares and 91,356,868 shares issued at March 31, 2021 and December 31, 2020, respectively0.9 0.9 
Additional paid-in capital 1,160.1
 1,151.9
Additional paid-in capital1,188.6 1,185.1 
Accumulated other comprehensive income 0.5
 0.1
Treasury stock, 17,575,527 shares and 17,516,814 shares, at cost, as of June 30, 2020 and December 31, 2019, respectively (694.1) (692.2)
Accumulated other comprehensive lossAccumulated other comprehensive loss(7.4)(7.2)
Treasury stock, 17,575,527 shares, at cost, as of March 31, 2021 and December 31, 2020, respectivelyTreasury stock, 17,575,527 shares, at cost, as of March 31, 2021 and December 31, 2020, respectively(694.1)(694.1)
Retained earnings 926.4
 1,205.6
Retained earnings423.2 522.0 
Non-controlling interests in subsidiaries 165.5
 169.0
Non-controlling interests in subsidiaries117.7 118.4 
Total stockholders’ equity 1,559.3
 1,835.3
Total stockholders’ equity1,028.9 1,125.1 
Total liabilities and stockholders’ equity $6,437.6
 $7,016.3
Total liabilities and stockholders’ equity$6,744.0 $6,134.1 



See accompanying notes to condensed consolidated financial statements

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Financial Statements

Delek US Holdings, Inc.
Condensed Consolidated Statements of Income (Unaudited)
(In millions, except share and per share)share data)
  Three Months Ended Six Months Ended
  June 30, June 30,
  2020 2019 2020 2019
Net revenues $1,535.5
 $2,480.3
 $3,356.7
 $4,680.2
Cost of sales:        
Cost of materials and other 1,277.8
 2,067.7
 3,188.4
 3,767.1
Operating expenses (excluding depreciation and amortization presented below) 103.4
 135.8
 232.6
 276.7
Depreciation and amortization 53.6
 42.6
 100.6
 81.9
Total cost of sales 1,434.8
 2,246.1
 3,521.6
 4,125.7
Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below) 24.4
 26.5
 49.7
 52.3
General and administrative expenses 61.7
 69.5
 127.4
 131.7
Depreciation and amortization 6.0
 7.5
 11.6
 15.0
Other operating income, net (14.2) (3.6) (14.9) (1.2)
Total operating costs and expenses 1,512.7
 2,346.0
 3,695.4
 4,323.5
Operating income (loss) 22.8
 134.3
 (338.7) 356.7
Interest expense 29.8
 32.8
 66.1
 61.5
Interest income (0.5) (3.3) (2.2) (5.8)
Income from equity method investments (10.7) (9.3) (15.8) (11.9)
Gain on sale of non-operating refinery (56.9) —
 (56.9) —
Other (income) expense, net (1.5) 4.9
 (2.4) 3.5
Total non-operating (income) expense, net (39.8) 25.1
 (11.2) 47.3
Income (loss) before income tax (benefit) expense 62.6
 109.2
 (327.5) 309.4
Income tax (benefit) expense (35.9) 24.6
 (119.0) 70.4
Income (loss) from continuing operations, net of tax 98.5
 84.6
 (208.5) 239.0
Discontinued operations:        
Loss from discontinued operations, including gain (loss) on sale of discontinued operations —
 (1.0) —
 (1.0)
Income tax benefit —
 (0.2) —
 (0.2)
Loss from discontinued operations, net of tax —
 (0.8) —
 (0.8)
Net income (loss) 98.5
 83.8
 (208.5) 238.2
Net income attributed to non-controlling interests 10.8
 6.5
 18.2
 11.6
Net income (loss) attributable to Delek $87.7
 $77.3
 $(226.7) $226.6
Basic income (loss) per share:        
Income (loss) from continuing operations $1.19
 $1.02
 $(3.08) $2.95
Loss from discontinued operations —
 $(0.01) —
 (0.01)
Basic income (loss) per share $1.19
 $1.01
 $(3.08) $2.94
Diluted income (loss) per share:        
Income (loss) from continuing operations $1.18
 $1.01
 $(3.08) $2.92
Loss from discontinued operations —
 (0.01) —
 (0.01)
Diluted income (loss) per share $1.18
 $1.00
 $(3.08) $2.91
Dividends declared per common share outstanding $0.31
 $0.28
 $0.62
 $0.55
Three Months Ended
March 31,
 20212020
Net revenues$2,392.2 $1,821.2 
Cost of sales: 
Cost of materials and other2,205.5 1,910.6 
Operating expenses (excluding depreciation and amortization presented below)128.0 129.2 
Depreciation and amortization62.3 47.0 
Total cost of sales2,395.8 2,086.8 
Operating expenses related to retail and wholesale business (excluding depreciation and amortization presented below)21.3 25.3 
General and administrative expenses47.1 65.7 
Depreciation and amortization6.2 5.6 
Other operating loss (income), net1.9 (0.7)
Total operating costs and expenses2,472.3 2,182.7 
Operating loss(80.1)(361.5)
Interest expense29.6 36.3 
Interest income(0.2)(1.7)
Income from equity method investments(4.8)(5.1)
Other income, net(1.0)(0.9)
Total non-operating expense, net23.6 28.6 
Loss before income tax benefit(103.7)(390.1)
Income tax benefit(12.4)(83.1)
Net loss(91.3)(307.0)
Net income attributed to non-controlling interests7.3 7.4 
Net loss attributable to Delek$(98.6)$(314.4)
Basic loss per share$(1.34)$(4.28)
Diluted loss per share$(1.34)$(4.28)
Dividends declared per common share outstanding$0 $0.31 


See accompanying notes to condensed consolidated financial statements

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Financial Statements

Delek US Holdings, Inc.
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
(In millions)
Three Months Ended
March 31,
 20212020
Net loss$(91.3)$(307.0)
Other comprehensive income (loss):
Commodity contracts designated as cash flow hedges:
Net (loss) gain related to commodity cash flow hedges(0.2)1.8 
Income tax expense0 0.4 
Net comprehensive (loss) income on commodity contracts designated as cash flow hedges(0.2)1.4 
Other loss, net of taxes0 (0.3)
Total other comprehensive (loss) gain(0.2)1.1 
Comprehensive loss(91.5)(305.9)
Comprehensive income attributable to non-controlling interest7.3 7.4 
Comprehensive loss attributable to Delek$(98.8)$(313.3)
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Net income (loss) $98.5
 $83.8
 $(208.5) $238.2
Other comprehensive income (loss):        
Commodity contracts designated as cash flow hedges:        
Net gains (losses) related to commodity cash flow hedges (1.4) (16.5) 0.3
 (3.4)
Income tax expense (benefit) (0.3) (3.5) —
 (0.7)
Net comprehensive income (loss) on commodity contracts designated as cash flow hedges (1.1) (13.0) 0.3
 (2.7)
Other income, net of taxes 0.4
 —
 0.1
 0.4
Total other comprehensive income (loss) (0.7) (13.0) 0.4
 (2.3)
Comprehensive income (loss) 97.8
 70.8
 (208.1) 235.9
Comprehensive income attributable to non-controlling interest 10.8
 6.5
 18.2
 11.6
Comprehensive income (loss) attributable to Delek $87.0
 $64.3
 $(226.3) $224.3


See accompanying notes to condensed consolidated financial statements


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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 March 31, 2021
Common StockAdditional Paid-in CapitalAccumulated Other Comprehensive IncomeRetained EarningsTreasury StockNon-Controlling Interest in SubsidiariesTotal Stockholders' Equity
SharesAmountSharesAmount
Balance at December 31, 202091,356,868$0.9 $1,185.1 $(7.2)$522.0 (17,575,527)$(694.1)$118.4 $1,125.1 
Net (loss) income—— — — (98.6)— — 7.3 (91.3)
Other comprehensive loss related to commodity contracts, net—— — (0.2)— — — — (0.2)
Distributions to non-controlling interests—— — — — — — (8.0)(8.0)
Equity-based compensation expense—— 4.6 — — — — 0 4.6 
Taxes paid due to the net settlement of equity-based compensation—— (1.1)— — — — 0 (1.1)
Exercise of equity-based awards93,856 — — — — — — — — 
Other— — 0 0 (0.2)— 0 0 (0.2)
Balance at March 31, 202191,450,724 $0.9 $1,188.6 $(7.4)$423.2 (17,575,527)$(694.1)$117.7 $1,028.9 








  Three Months Ended June 30, 2020
  Common StockAdditional Paid-in Capital Accumulated Other Comprehensive Income Retained Earnings Treasury StockNon-Controlling Interest in Subsidiaries Total Stockholders' Equity
  Shares Amount Shares Amount 
Balance atMarch 31, 202091,089,920
 $0.9
 $1,157.4
 $1.2
 $861.6
 (17,575,527) $(694.1) $162.9
 $1,489.9
Net income—
 —
 —
 —
 87.7
 —
 —
 10.8
 98.5
Other comprehensive loss related to commodity contracts, net—
 —
 —
 (1.1) —
 —
 —
 —
 (1.1)
Common stock dividends ($0.31 per share)—
 —
 —
 —
 (22.9) —
 —
 —
 (22.9)
Distributions to non-controlling interests—
 —
 —
 —
 —
 —
 —
 (8.2) (8.2)
Equity-based compensation expense—
 —
 4.7
 —
 —
 —
 —
 —
 4.7
Repurchase of non-controlling interests—
 —
 (0.8) —
 —
 —
 —
 —
 (0.8)
Taxes paid due to the net settlement of equity-based compensation—
 —
 (1.2) —
 —
 —
 —
 —
 (1.2)
Exercise of equity-based awards143,044
 —
 —
 —
 —
 —
 —
 —
 —
Other—
 —
 —
 0.4
 —
 —
 —
 —
 0.4
Balance atJune 30, 202091,232,964
 $0.9
 $1,160.1
 $0.5
 $926.4
 (17,575,527) $(694.1) $165.5
 $1,559.3




















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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, 2019
  Common Stock Additional Paid-in Capital Accumulated Other Comprehensive Income Retained Earnings Treasury Stock Non-Controlling Interest in Subsidiaries Total Stockholders' Equity
  Shares Amount    Shares Amount  
Balance atMarch 31, 201990,722,641
 $0.9
 $1,135.5
 $39.3
 $1,110.1
 (13,769,424) $(560.3) $173.0
 $1,898.5
Net income—
 —
 —
 —
 77.3
 —
 —
 6.5
 83.8
Other comprehensive loss related to commodity contracts, net—
 —
 —
 (13.0) —
 —
 —
 —
 (13.0)
Common stock dividends ($0.28 per share)—
 —
 —
 —
 (21.5) —
 —
 —
 (21.5)
Distribution to non-controlling interest—
 —
 —
 —
 —
 —
 —
 (7.9) (7.9)
Equity-based compensation expense—
 —
 6.7
 —
 —
 —
 —
 0.1
 6.8
Repurchase of common stock—
 —
 —
 —
 —
 (1,647,078) (58.6) —
 (58.6)
Taxes paid due to the net settlement of equity-based compensation—
 —
 (2.4) —
 —
 —
 —
 —
 (2.4)
Exercise of equity-based awards139,057
 —
 —
 —
 —
 —
 —
 —
 —
Other—
 —
 0.5
 —
 —
 —
 —
 —
 0.5
Balance atJune 30, 201990,861,698
 $0.9
 $1,140.3
 $26.3
 $1,165.9
 (15,416,502) $(618.9) $171.7
 $1,886.2



















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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, 2020
  Common StockAdditional Paid-in Capital Accumulated Other Comprehensive Income Retained Earnings Treasury StockNon-Controlling Interest in Subsidiaries Total Stockholders' Equity
  Shares Amount Shares Amount 
Balance atDecember 31, 201990,987,025
 $0.9
 $1,151.9
 $0.1
 $1,205.6
 (17,516,814) $(692.2) $169.0
 $1,835.3
Cumulative effect of adopting accounting principle regarding measurement of credit losses on financial instruments, net—
 —
 —
 —
 (6.5) —
 —
 —
 (6.5)
Net (loss) income—
 —
 —
 —
 (226.7) —
 —
 18.2
 (208.5)
Other comprehensive income related to commodity contracts, net—
 —
 —
 0.3
 —
 —
 —
 —
 0.3
Common stock dividends ($0.62 per share)—
 —
 —
 —
 (46.0) —
 —
 —
 (46.0)
Distributions to non-controlling interests—
 —
 —
 —
 —
 —
 —
 (16.8) (16.8)
Equity-based compensation expense—
 —
 10.9
 —
 —
 —
 —
 0.1
 11.0
Repurchase of common stock—
 —
 —
 —
 —
 (58,713) (1.9) —
 (1.9)
Repurchases of non-controlling interests—
 —
 (0.8) —
 —
 —
 —
 (5.0) (5.8)
Taxes paid due to the net settlement of equity-based compensation—
 —
 (1.9) —
 —
 —
 —
 —
 (1.9)
Exercise of equity-based awards245,939
 —
 —
 —
 —
 —
 —
 —
 —
Other—
 —
 —
 0.1
 —
 —
 —
 —
 0.1
Balance atJune 30, 202091,232,964
 $0.9
 $1,160.1
 $0.5
 $926.4
 (17,575,527) $(694.1) $165.5
 $1,559.3









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Financial Statements

Delek US Holdings, Inc.
Condensed Consolidated Statements of Changes in Stockholders' Equity (Unaudited) (Continued)
(In millions, except share and per share data)
Three Months Ended March 31, 2020
Common StockAdditional Paid-in CapitalAccumulated Other Comprehensive IncomeRetained EarningsTreasury StockNon-Controlling Interest in SubsidiariesTotal Stockholders' Equity
SharesAmountSharesAmount
Balance at December 31, 201990,987,025 $0.9 $1,151.9 $0.1 $1,205.6 (17,516,814)$(692.2)$169.0 $1,835.3 
Cumulative effect of adopting accounting principle regarding measurement of credit losses on financial instruments, net— — — — (6.5)— — — (6.5)
Net (loss) income— — — — (314.4)— — 7.4 (307.0)
Other comprehensive income related to commodity contracts, net— — — 1.4 — — — — 1.4 
Common stock dividends ($0.31 per share)— — — — (23.1)— — 0 (23.1)
Distribution to non-controlling interest— — — — — — — (8.6)(8.6)
Equity-based compensation expense— — 6.2 — — — — 0.1 6.3 
Repurchase of common stock— — — — — (58,713)(1.9)— (1.9)
Repurchases of non-controlling interests— — — — — — — (5.0)(5.0)
Taxes paid due to the net settlement of equity-based compensation— — (0.7)— — — — 0 (0.7)
Exercise of equity-based awards102,895 — — — — — — — — 
Other— — 0 (0.3)0 — 0 0 (0.3)
Balance at March 31, 202091,089,920 $0.9 $1,157.4 $1.2 $861.6 (17,575,527)$(694.1)$162.9 $1,489.9 
  Six Months Ended June 30, 2019
  Common Stock Additional Paid-in Capital Accumulated Other Comprehensive Income Retained Earnings Treasury Stock Non-Controlling Interest in Subsidiaries Total Stockholders' Equity
  Shares Amount    Shares Amount  
Balance atDecember 31, 201890,478,075
 $0.9
 $1,135.4
 $28.6
 $981.8
 (12,477,780) $(514.1) $175.5
 $1,808.1
Net income—
 —
 —
 —
 226.6
 —
 —
 11.6
 238.2
Other comprehensive loss related to commodity contracts, net—
 —
 —
 (2.7) —
 —
 —
 —
 (2.7)
Common stock dividends ($0.55 per share)—
 —
 —
 —
 (42.5) —
 —
 —
 (42.5)
Distribution to non-controlling interest—
 —
 —
 —
 —
 —
 —
 (15.6) (15.6)
Equity-based compensation expense—
 —
 11.6
 —
 —
 —
 —
 0.2
 11.8
Repurchase of common stock—
 —
 —
 —
 —
 (2,938,722) (104.8) —
 (104.8)
Taxes paid due to the net settlement of equity-based compensation—
 —
 (6.9) —
 —
 —
 —
 —
 (6.9)
Exercise of equity-based awards383,623
 —
 —
 —
 —
 —
 —
 —
 —
Other—
 —
 0.2
 0.4
 —
 —
 —
 —
 0.6
Balance atJune 30, 201990,861,698
 $0.9
 $1,140.3
 $26.3
 $1,165.9
 (15,416,502) $(618.9) $171.7
 $1,886.2

See accompanying notes to condensed consolidated financial statements


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Financial Statements

Delek US Holdings, Inc.
Condensed Consolidated Statements of Cash Flows (Unaudited)
(In millions)
 Three Months Ended March 31,
20212020
Cash flows from operating activities:
Net loss$(91.3)$(307.0)
Adjustments to reconcile net loss to net cash used in operating activities:  
Depreciation and amortization68.5 52.6 
Other amortization/accretion3.0 2.2 
Non-cash lease expense15.3 13.3 
Deferred income taxes5.1 (24.5)
Income from equity method investments(4.8)(5.1)
Dividends from equity method investments5.7 4.9 
Non-cash lower of cost or market/net realizable value adjustment(20.4)280.8 
Equity-based compensation expense4.6 6.3 
Other0.9 1.1 
Changes in assets and liabilities:  
Accounts receivable(192.3)351.6 
Inventories and other current assets(304.2)250.9 
Fair value of derivatives(91.9)(36.1)
Accounts payable and other current liabilities524.5 (546.3)
Obligation under Supply and Offtake Agreements51.6 (199.9)
Non-current assets and liabilities, net(8.6)1.1 
Net cash used in operating activities(34.3)(154.1)
Cash flows from investing activities:  
Equity method investment contributions(1.5)(27.1)
Distributions from equity method investments4.0 69.4 
Purchases of property, plant and equipment(48.3)(189.2)
Purchase of intangible assets(0.5)0 
Proceeds from sale of property, plant and equipment0.2 0.3 
Net cash used in investing activities(46.1)(146.6)
  Six Months Ended June 30,
  2020 2019
Cash flows from operating activities:    
Net (loss) income $(208.5) $238.2
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:  
  
Depreciation and amortization 112.2
 96.9
Other amortization/accretion 4.8
 4.6
Non-cash lease expense 21.9
 16.5
Deferred income taxes 65.9
 16.0
Income from equity method investments (15.8) (11.9)
Dividends from equity method investments 14.3
 4.2
Loss on disposal of assets —
 3.6
Gain on sale of non-operating refinery (56.9) —
Equity-based compensation expense 11.0
 11.8
Excess tax deficiency (benefit) of equity-based compensation 1.6
 (1.7)
Loss from discontinued operations —
 0.8
Changes in assets and liabilities:  
  
Accounts receivable 307.2
 (332.6)
Inventories and other current assets 200.1
 (192.5)
Fair value of derivatives (23.6) 22.3
Accounts payable and other current liabilities (594.6) 349.5
Obligation under Supply and Offtake Agreements (163.3) 18.3
Non-current assets and liabilities, net 0.6
 (8.6)
Net cash (used in) provided by operating activities (323.1) 235.4
Cash flows from investing activities:  
  
Equity method investment contributions (29.5) (136.4)
Distributions from equity method investments 71.0
 0.8
Purchases of property, plant and equipment (235.4) (199.9)
Purchase of intangible assets (2.1) —
Proceeds from sale of property, plant and equipment 0.2
 0.3
Proceeds from sale of retail stores —
 5.8
Proceeds from sale of non-operating refinery 39.9
 —
Net cash used in investing activities (155.9) (329.4)

Delek US Holdings, Inc.
Condensed Consolidated Statements of Cash Flows (Unaudited) (continued)
(In millions)
Three Months Ended March 31,
20212020
 Six Months Ended June 30,
 2020 2019
Cash flows from financing activities:  
  Cash flows from financing activities:  
Proceeds from long-term revolvers $1,583.7
 $987.5
Proceeds from long-term revolvers$609.0 $1,230.2 
Payments on long-term revolvers (1,352.1) (1,072.5)Payments on long-term revolvers(568.1)(1,053.5)
Proceeds from term debt 185.0
 246.7
Payments on term debt (31.2) (29.1)Payments on term debt(23.3)(27.9)
Proceeds from product financing agreements 86.4
 19.8
Proceeds from product financing agreements277.2 42.0 
Repayments of product financing agreements (26.5) (15.6)Repayments of product financing agreements(199.3)(21.0)
Taxes paid due to the net settlement of equity-based compensation (1.9) (6.9)Taxes paid due to the net settlement of equity-based compensation(1.1)(0.7)
Repurchase of common stock (1.9) (104.8)Repurchase of common stock0 (1.9)
Repurchase of non-controlling interest (5.8) —
Repurchase of non-controlling interest0 (5.0)
Distribution to non-controlling interest (16.8) (15.6)Distribution to non-controlling interest(8.0)(8.6)
Dividends paid (46.0) (42.5)Dividends paid0 (23.1)
Deferred financing costs paid (0.2) (0.9)Deferred financing costs paid0 (0.2)
Net cash provided by (used in) financing activities 372.7
 (33.9)
Net decrease in cash and cash equivalents (106.3) (127.9)
Net cash provided by financing activitiesNet cash provided by financing activities86.4 130.3 
Net increase (decrease) in cash and cash equivalentsNet increase (decrease) in cash and cash equivalents6.0 (170.4)
Cash and cash equivalents at the beginning of the period 955.3
 1,079.3
Cash and cash equivalents at the beginning of the period787.5 955.3 
Cash and cash equivalents of continuing operations at the end of the period $849.0
 $951.4
Cash and cash equivalents at the end of the periodCash and cash equivalents at the end of the period$793.5 $784.9 
Supplemental disclosures of cash flow information:    Supplemental disclosures of cash flow information:  
Cash paid during the period for:    Cash paid during the period for:  
Interest, net of capitalized interest of $0.2 million and $0.7 million in the 2020 and 2019 periods, respectively $66.1
 $60.4
Interest, net of capitalized interest of $0.4 million and $0.2 million in the 2021 and 2020 periods, respectivelyInterest, net of capitalized interest of $0.4 million and $0.2 million in the 2021 and 2020 periods, respectively$142.1 $32.2 
Income taxes $0.2
 $66.1
Income taxes$0.1 $0.2 
Non-cash investing activities:    Non-cash investing activities: 
(Decrease) increase in accrued capital expenditures $(33.1) $14.5
Increase in accrued capital expendituresIncrease in accrued capital expenditures$18.8 $1.1 
Non-cash financing activities:    Non-cash financing activities:
Non-cash lease liability arising from recognition of right of use assets upon adoption of Accounting Standards Update ("ASU") 2016-02 $—
 $211.0
Non-cash lease liability arising from obtaining right of use assets during the period $22.2
 $8.1
Non-cash lease liability arising from obtaining right of use assets during the period$19.6 $6.8 



See accompanying notes to condensed consolidated financial statements

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Notes to Condensed Consolidated Financial Statements (Unaudited)


Note 1 - Organization and Basis of Presentation
Delek US Holdings, Inc. operates through its consolidated subsidiaries, which include Delek US Energy, Inc. ("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 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 February 28, 2020March 1, 2021 (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, 20192020 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.entity ("VIE"). As the indirect owner of the general partner of Delek Logistics, we have the ability to direct the activities of this entity that most significantly impact its economic performance. We are also considered to be the primary beneficiary for accounting purposes for this entity and are Delek Logistics' primary customer. As Delek Logistics does not derive an amount of gross margin material to us from third parties, there is limited risk to Delek associated with Delek Logistics' operations. However, in the event that Delek Logistics incurs a loss, our operating results will reflect such loss, net of intercompany eliminations, to the extent of our ownership interest in this entity.
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.
Accounting Policies
With the exception of the policy updates below, there have been no new or material changes to the significant accounting policies discussed in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2019.2020.
Risks and Uncertainties Arising from the COVID-19 Pandemic and the OPEC Production Disputes
The recent outbreak of COVID-19 and its development into a pandemic in March 2020 (the "COVID-19 Pandemic" or the "Pandemic") has resulted incontinues to have an on-going impact. The restrictions imposed to prevent its spread, the challenges with the vaccination rollout, and the spread of new variants of the virus, continue to cause significant economic disruption globally, including in the U.S. and specific geographic areas where we operate. Actions takenCompared to the prior year, the first quarter of 2021 has witnessed economic recovery trends including a resumption of flights by various governmental authorities, individualsmajor airlines and companies around the world to prevent the spread of COVID-19 through social distancing have restricted travel, many business operations, public gatherings and the overall level of individual movement and in-person interaction across the globe. This has in turn significantly reduced global economic activity and resulted in airlines dramatically cutting back on flights and a decrease inincreased motor vehicle use at a time when seasonal driving patterns typically result in an increase of consumer demand for gasoline.use. As a result, there has also been a declinean increase in the demand for, and thus also the market prices of, crude oil and certain of our products. In April and June 2020, an agreement was reached to cut oil production between the members of the Organization of Petroleum Exporting Countries ("OPEC") and other leading oil producing countries (together with OPEC, “OPEC+”), as part of the efforts to resolve the oil production disputes ("OPEC Production Disputes") that significantly affected crude oil prices beginning in first quarter of 2020 and to provide stability in the oil markets. While OPEC+ have reached an agreement to cut oil production, uncertaintyUncertainty about the duration of the COVID-19 Pandemic has caused storage constraints in the United States resulting from over-supply of produced oil. Therefore, downward pressure on commodity prices has remained and could continueexist for the foreseeable future.
Uncertainties related to the impact of the COVID-19 Pandemic and other events exist that could impact our future results of operations and financial position, the nature of which and the extent to which are currently unknown. To the extent these uncertainties have been identified and are believed to have an impact on our current period results of operations or financial position based on the requirements for assessing such financial statement impact under GAAP, we have considered them in the preparation of our unaudited financial statements as of and for the three and six months ended June 30, 2020.March 31, 2021. The application of accounting policies impacted by such considerations include (but are not necessarily limited to) the following:
The interim evaluation of the risk of credit losses and the determination of our allowance for credit losses, pursuant to GAAP;
The interim evaluation of long-lived assets for potential impairment, where indicators exist, as defined by GAAP;
•The interim evaluation of indefinite-lived intangibles and goodwill for potential impairment, where indicators exist, as defined by GAAP;

•The interim evaluation of long-lived assets for potential impairment, where indicators exist, as defined by GAAP;
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Notes to Condensed Consolidated Financial Statements (Unaudited)

•The interim evaluation of joint ventures for potential impairment, where indicators exist, as defined by GAAP;
•The evaluation of derivatives and hedge accounting for counterparty risk and changes in forecasted transactions, as provided for under GAAP;
•The evaluation of inventory valuation allowances that may be warranted under the lower of cost or net realizable value analysis, for first-in, first-out (“FIFO”), and the lower of cost or market analysis, for last-in, first-out ("LIFO"), pursuant to GAAP;
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Notes to Condensed Consolidated Financial Statements (Unaudited)
•The consideration of debt modifications and/or covenant requirements, as applicable;
•The evaluation of commitments and contingencies, including changes in concentrations, as applicable;
•The interim evaluation of the impact of changing forecasts on our assessment of deferred tax asset valuation allowances and annual effective tax rates; and
•The interim evaluation of our ability to continue as a going concern.
Credit Losses
Under ASU 2016-13, Financial Instruments - Measurement of Credit Losses on Financial Instruments (as codified in Accounting Standards Codification ("ASC") 326), we have applied the expected credit loss model for recognition and measurement of impairments in financial assets measured at amortized cost or at fair value through other comprehensive income including accounts receivables. The expected credit loss model is also applied for notes receivables and contractual holdbacks to which ASU 2016-13 applies and which are not accounted for at fair value through profit or loss. The loss allowance for the financial asset is measured at an amount equal to the lifetime expected credit losses. If the credit risk on the financial asset has decreased significantly since initial recognition, the loss allowance for the financial asset is re-measured. Changes in loss allowances are recognized in profit and loss. For trade receivables, a simplified impairment approach is applied recognizing expected lifetime losses from initial recognition.
Reclassifications
Certain prior period amounts have been reclassified in order to conform to the current period presentation.
New Accounting Pronouncements Adopted During 20202021
ASU 2018-15, Intangible - Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract2020-01, Investments—Equity Securities (Topic 321), Investments—Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815)—Clarifying the Interactions between Topic 321, Topic 323, and Topic 815
In August 2018,January 2020, the Financial Account Standards Board ("FASB") issued Accounting Standards Board (the "FASB"Update ("ASU") issued2020-01 which is intended to clarify interactions between the guidance related to customers’ accountingaccount for implementation costs incurredcertain equity securities under Topics 321, 323 and 815, and improve current GAAP by reducing diversity in a cloud computing arrangement that is considered a service contract. This pronouncement aligns the requirements for capitalizing implementation costs in such arrangements with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. Thispractice and increasing comparability of accounting. The pronouncement is effective for fiscal years and for interim periods within those fiscal years beginning after December 15, 2019.2020. We adopted this guidance on January 1, 20202021 and the adoption did not have a material impact on our business, financial condition or results of operations.
ASU 2018-13, Fair Value Measurement - Changes to2019-12, Simplifying the Disclosure RequirementsAccounting for Fair Value MeasurementIncome Taxes
In August 2018,December 2019, the FASB issued guidance intended to simplify various aspects related to disclosure requirementsaccounting for fair value measurements. The pronouncement eliminates, modifiesincome taxes, eliminate certain exceptions within Accounting Standards Codification ("ASC") 740, Income Taxes (“ASC 740”) and adds disclosure requirements for fair value measurements.clarify certain aspects of the current guidance to promote consistency among reporting entities. The pronouncement is effective for fiscal years and for interim periods within those fiscal years beginning after December 15, 2019, with early adoption permitted.2020. We adopted this guidance on January 1, 20202021 and the adoption did not have a material impact on our business, financial condition or results of operations. See Note 10.
ASU 2016-13, Financial Instruments2018-14, Compensation - Measurement of Credit Losses on Financial InstrumentsChanges to the Disclosure Requirements for Defined Benefit Plans
In June 2016,August 2018, the FASB issued guidance requiring the measurement of all expected credit lossesrelated to disclosure requirements for financial assets held at the reporting date based on historical experience, current conditions,defined benefit plans. The pronouncement eliminates, modifies and reasonable and supportable forecasts. Organizations will now use forward-looking information to better inform their credit loss estimates. This guidanceadds disclosure requirements for defined benefit plans. The pronouncement is effective for interim and annual periodsfiscal years beginning after December 15, 2019.2020. We adopted this guidance on January 1, 2020 using2021 and the modified retrospective approach as of the adoption date. The adoption did not have a material impact on the Company’s operatingour business, financial condition or results financial position or disclosures.

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Notes to Condensed Consolidated Financial Statements (Unaudited)

of operations.
Accounting Pronouncements Not Yet Adopted
ASU 2020-06, Debt—Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging—Contracts in Entity's Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity
In August 2020, the FASB issued ASU 2020-06, which is intended to simplify the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts in an entity's own equity. The guidance allows for either full retrospective adoption or modified retrospective adoption. The pronouncement is effective for fiscal years and interim periods within those fiscal years beginning after December 15, 2021, and early adoption is permitted. The Company is evaluating the impact of this guidance but does not currently expect adopting this new guidance will have a material impact on its condensed consolidated financial statements and related disclosures.
ASU 2020-04, Facilitation of the Effects of Reference Rate Reform on Financial Reporting (Topic 848)
In March 2020, the FASB issued an amendment which is intended to provide temporary optional expedients and exceptions to GAAP guidance on contracts, hedge accounting and other transactions affected by the expected market transition from the London Interbank Offered Rate ("LIBOR") and other interbank rates. This guidance is effective for all entities at anytimeany time beginning on March 12, 2020 through December 31, 2022 and may be applied from the beginning of an interim period that includes the issuance date of the ASU. The Company is currently evaluating the impact this guidance may have on its condensed consolidated financial statements and related disclosures.
ASU 2020-01, Investments—Equity Securities (Topic 321), Investments—Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815)—Clarifying the Interactions between Topic 321, Topic 323, and Topic 815
In January 2020, the FASB issued ASU 2020-01 which is intended to clarify interactions between the guidance to account for certain equity securities under Topics 321, 323 and 815, and improve current GAAP by reducing diversity in practice and increasing comparability of accounting. The pronouncement is effective for fiscal years and interim periods within those fiscal years beginning after December 15, 2020, and early adoption is permitted. The Company is currently evaluating the impact this guidance may have on its consolidated financial statements and related disclosures.
ASU 2019-12, Simplifying the Accounting for Income Taxes
In December 2019, the FASB issued guidance intended to simplify various aspects related to accounting for income taxes, eliminate certain exceptions within ASC 740 and clarify certain aspects of the current guidance to promote consistency among reporting entities. The pronouncement is effective for fiscal years and for interim periods within those fiscal years beginning after December 15, 2020, with early adoption permitted. We expect to adopt this guidance on the effective date and are currently evaluating the impact that adopting this new guidance will have on our business, financial condition and results of operations.
ASU 2018-14, Compensation - Changes to the Disclosure Requirements for Defined Benefit Plans
In August 2018, the FASB issued guidance related to disclosure requirements for defined benefit plans. The pronouncement eliminates, modifies and adds disclosure requirements for defined benefit plans. The pronouncement is effective for fiscal years beginning after December 15, 2020, and early adoption is permitted. We expect to adopt this guidance on the effective date and do not expect adopting this new guidance will have a material impact on our business, financial condition or results of operations.

Note 2 - 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 9);
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Notes to Condensed Consolidated Financial Statements (Unaudited)
•wholesale crude operations;
•Alon's asphalt terminal operations; and
•intercompany eliminations.
Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each of the reportable segments based on the segment contribution margin. Segment contribution margin is defined as net revenues less cost of materials and other and operating expenses, excluding depreciation and amortization.
During the first quarter of 2020, we revised the structure of the internal financial information reviewed by management and began allocating the results of hedging activity associated with managing risks of our refineries, previously reported in corporate, other and eliminations, to our refining segment. The historical results of this hedging activity have been reclassified to conform to the current presentation. The assets and/or liabilities associated with this hedging activity have not been allocated to the refining segment.
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 30, 2020,March 31, 2021, including the following:
•75,000 bpd Tyler, Texas refinery (the "Tyler refinery");
•80,000 bpd El Dorado, Arkansas refinery (the "El Dorado refinery");

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Notes to Condensed Consolidated Financial Statements (Unaudited)

•73,000 bpd Big Spring, Texas refinery (the "Big Spring refinery"); and
•74,000 bpd Krotz Springs, Louisiana refinery (the "Krotz Springs refinery"); and
a non-operating refinery located in Bakersfield, California, which was sold May 7, 2020..
The refining segment also owns and operates 3 biodiesel facilities involved in the production of biodiesel fuels and related activities, located in Crossett, Arkansas, Cleburne, Texas and New Albany, Mississippi (acquired in October 2019).Mississippi. The biodiesel industry has historically been substantially aided by federal and state tax incentives. One tax incentive program that has been significant to our renewable fuels facilities is the federal blender's tax credit (also known as the biodiesel tax credit or "BTC"). The BTC provides a $1.00 refundable tax credit per gallon of pure biodiesel to the first blender of biodiesel with petroleum-based diesel fuel. The blender's tax credit was re-enacted in December 2019 for the years 2020 through 2022 and was retroactively reinstated for 2018 and 2019.2022.
On May 7, 2020, we sold our equity interests in Alon Bakersfield Property, Inc., an indirect wholly-owned subsidiary that ownsowned our non-operating refinery located in Bakersfield, California, to a subsidiary of Global Clean Energy Holdings, Inc. (“GCE”) for total cash consideration of $40$40.0 million. As a result of this sale, we recognized a gain of $56.9$56.8 million during 2020, none of which was recognized during the first quarter, largely due to the buyer assuming substantially all of the asset retirement obligations and environmental liabilities associated with this refinery, which is included in gain on sale of non-operating refinery on the accompanying condensed consolidated statements of income.refinery. As part of the transaction, GCE granted a call option to Delek to acquire up to a 33 1/3% limited member interest in the acquiring subsidiary of GCE for up to $13.3 million, subject to certain adjustments. Such option is exercisable by Delek through the 90th day after GCE demonstrates commercial operations, as contractually defined.defined, which has not yet occurred as of March 31, 2021.
The refining segment's petroleum-based products are marketed primarily in the south central, southwestern and western regions of the United States. This 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, Alon sells motor fuels through its wholesale distribution network on an unbranded basis.
Logistics Segment
Our logistics segment owns and operates crude oil and refined products logistics and marketing assets. The logistics segment generates revenue by charging fees for gathering, transporting and storing crude oil and for marketing, distributing, transporting and storing intermediate and refined products in select regions of the southeastern United States and West Texas for our refining segment and third parties, and sales of wholesale products in the West Texas market.
Retail Segment
Our retail segment consists of 253 owned and leased convenience store sites as of June 30, 2020,March 31, 2021, located primarily in Central and West Texas and New Mexico. These convenience stores typically offer various grades of gasoline and diesel primarily under the Alon or Delek brand name and food products, food service, tobacco products, non-alcoholic and alcoholic beverages, general merchandise as well as money orders to the public, primarily under the 7-Eleven and Alon brand names. Substantially all of the motor fuel sold through our retail segment is supplied by our Big Spring refinery, which is transferred to the retail segment at prices substantially determined by reference to published commodity pricing information. In November 2018, we terminated the license agreement with 7-Eleven, Inc. ThisThe terms of such agreement was amended in April 2020 to extend date forand subsequent amendments require the required removal of all 7-Eleven branding on a store-by-store basis fromby December 31, 2021 to December 31, 2022. Merchandise sales at our convenience store sites will continue to be sold under the 7-Eleven brand name until 7-Eleven branding is removed at such convenience store sites.2023.
Significant Inter-segment Transactions
All inter-segment transactions have been eliminated in consolidation and consist primarily of the following:
•refining segment refined product sales to the retail segment to be sold through the store locations;
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Notes to Condensed Consolidated Financial Statements (Unaudited)
•refining segment sales of asphalt and refined product to entities included in corporate, other and eliminations;
•logistics segment service fee revenue under service agreements with the refining segment based on the number of gallons sold and to share a portion of the margin achieved in return for providing marketing, sales and customer services;
•logistics segment sales of wholesale finished product to our refining segment; and
•logistics segment crude transportation, terminalling and storage fee revenue from our refining segment for the utilization of pipeline, terminal and storage assets.

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Notes to Condensed Consolidated Financial Statements (Unaudited)

Business Segment Operating Performance
The following is a summary of business segment operating performance as measured by contribution margin for the period indicated (in millions):
 Three Months Ended March 31, 2021
(In millions)RefiningLogisticsRetailCorporate,
Other and Eliminations		Consolidated
Net revenues (excluding inter-segment fees and revenues)$1,584.5 $56.7 $174.8 $576.2 $2,392.2 
Inter-segment fees and revenues155.6 96.2 0 (251.8)— 
Operating costs and expenses:     
Cost of materials and other1,647.7 81.1 136.5 340.2 2,205.5 
Operating expenses (excluding depreciation and amortization presented below)113.6 14.1 21.4 0.2 149.3 
Segment contribution margin$(21.2)$57.7 $16.9 $(16.0)37.4 
Depreciation and amortization$52.1 $10.7 $3.2 $2.5 68.5 
General and administrative expenses��  47.1 
Other operating expense, net   1.9 
Operating loss   $(80.1)
Capital spending (excluding business combinations)$57.8 $7.8 $0.8 $0.6 $67.0 
  Three Months Ended June 30, 2020
(In millions) Refining Logistics Retail Corporate,
Other and Eliminations		 Consolidated
Net revenues (excluding inter-segment fees and revenues) $1,001.9
 $27.3
 $165.4
 $340.9
 $1,535.5
Inter-segment fees and revenues 75.1
 90.4
 —
 (165.5) —
Operating costs and expenses:          
Cost of materials and other 928.6
 43.9
 119.6
 185.7
 1,277.8
Operating expenses (excluding depreciation and amortization presented below) 88.7
 12.4
 21.5
 5.2
 127.8
Segment contribution margin $59.7
 $61.4
 $24.3
 $(15.5) 129.9
Depreciation and amortization $44.8
 $8.7
 $3.3
 $2.8
 59.6
General and administrative expenses         61.7
Other operating income, net         (14.2)
Operating income         $22.8
Capital spending (excluding business combinations) $12.2
 $0.7
 $1.3
 $0.8
 $15.0

  Three Months Ended June 30, 2019
  
Refining (1)
 Logistics Retail 
Corporate,
Other and Eliminations (1)
 Consolidated
Net revenues (excluding inter-segment fees and revenues) $2,152.5
 $93.1
 $224.5
 $10.2
 $2,480.3
Inter-segment fees and revenues 
 215.3
 62.2
 —
 (277.5) —
Operating costs and expenses:          
Cost of materials and other 2,054.7
 93.8
 182.1
 (262.9) 2,067.7
Operating expenses (excluding depreciation and amortization presented below) 115.0
 17.3
 24.8
 5.2
 162.3
Segment contribution margin $198.1
 $44.2
 $17.6
 $(9.6) 250.3
Depreciation and amortization $33.2
 $6.7
 $4.2
 $6.0
 50.1
General and administrative expenses         69.5
Other operating income, net         (3.6)
Operating income         $134.3
Capital spending (excluding business combinations) $48.9
 $1.3
 $5.4
 $30.4
 $86.0

  Six Months Ended June 30, 2020
(In millions) Refining Logistics Retail Corporate,
Other and Eliminations		 Consolidated
Net revenues (excluding inter-segment fees and revenues) $2,571.1
 $84.2
 $344.0
 $357.4
 $3,356.7
Inter-segment fees and revenues 233.8
 196.9
 —
 (430.7) —
Operating costs and expenses:          
Cost of materials and other 2,835.2
 145.2
 263.7
 (55.7) 3,188.4
Operating expenses (excluding depreciation and amortization presented below) 200.4
 27.2
 43.7
 11.0
 282.3
Segment contribution margin $(230.7) $108.7
 $36.6
 $(28.6) (114.0)
Depreciation and amortization $82.0
 $15.0
 $6.2
 $9.0
 112.2
General and administrative expenses         127.4
Other operating income, net         (14.9)
Operating loss  
    
  
 $(338.7)
Capital spending (excluding business combinations) $180.3
 $3.7
 $7.5
 $11.8
 $203.3

 Three Months Ended March 31, 2020
RefiningLogisticsRetailCorporate,
Other and Eliminations		Consolidated
Net revenues (excluding inter-segment fees and revenues)$1,569.3 $56.8 $178.6 $16.5 $1,821.2 
Inter-segment fees and revenues
158.6 106.6 0 (265.2)— 
Operating costs and expenses:     
Cost of materials and other1,906.6 101.3 144.1 (241.4)1,910.6 
Operating expenses (excluding depreciation and amortization presented below)111.7 14.8 22.2 5.8 154.5 
Segment contribution margin$(290.4)$47.3 $12.3 $(13.1)(243.9)
Depreciation and amortization$37.2 $6.3 $2.9 $6.2 52.6 
General and administrative expenses    65.7 
Other operating income, net    (0.7)
Operating loss    $(361.5)
Capital spending (excluding business combinations)$168.1 $3.0 $6.2 $12.9 $190.2 
15
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Notes to Condensed Consolidated Financial Statements (Unaudited)

  Six Months Ended June 30, 2019
  
Refining (1)
 Logistics Retail 
Corporate,
Other and Eliminations (1)
 Consolidated
Net revenues (excluding inter-segment fees and revenues) $4,059.9
 $182.9
 $421.7
 $15.7
 $4,680.2
Inter-segment fees and revenues 
 399.9
 124.9
 —
 (524.8) —
Operating costs and expenses:          
Cost of materials and other 3,723.8
 190.1
 345.5
 (492.3) 3,767.1
Operating expenses (excluding depreciation and amortization presented below) 236.0
 33.4
 48.4
 11.2
 329.0
Segment contribution margin $500.0
 $84.3
 $27.8
 $(28.0) 584.1
Depreciation and amortization $64.3
 $13.2
 $8.5
 $10.9
 96.9
General and administrative expenses         131.7
Other operating income, net         (1.2)
Operating income         $356.7
Capital spending (excluding business combinations) $130.5
 $2.2
 $10.5
 $71.1
 $214.3

(1)
The refining segment results of operations for the three and six months ended June 30, 2019, includes hedging gains, a component of cost of materials and other, of $19.8 million and $27.4 million, respectively, which was previously included and reported in corporate, other and eliminations.
Other Segment Information
Total assets by segment were as follows as of June 30, 2020:March 31, 2021:
RefiningLogisticsRetailCorporate,
Other and Eliminations		Consolidated
Total assets$6,527.9 $948.9 $255.3 $(988.1)$6,744.0 
Less:
Inter-segment notes receivable(1,372.8)0 0 1,372.8 — 
Inter-segment right of use lease assets(346.4)0 0 346.4 — 
Total assets, excluding inter-segment notes receivable and right of use assets$4,808.7 $948.9 $255.3 $731.1 $6,744.0 
  Refining Logistics Retail Corporate,
Other and Eliminations		 Consolidated
Total assets $6,142.9
 $973.8
 $256.3
 $(935.4) $6,437.6
Less:          
Inter-segment notes receivable (1,440.3) —
 —
 1,440.3
 —
Inter-segment right of use lease assets (394.5) —
 —
 394.5
 —
Total assets, excluding inter-segment notes receivable and right of use assets $4,308.1
 $973.8
 $256.3
 $899.4
 $6,437.6
Property, plant and equipment and accumulated depreciation as of June 30, 2020March 31, 2021 and depreciation expense by reporting segment for the three and six months ended June 30, 2020March 31, 2021 are as follows (in millions):
RefiningLogisticsRetailCorporate,
Other and Eliminations		Consolidated
Property, plant and equipment$2,619.3 $699.6 $165.8 $96.0 $3,580.7 
Less: Accumulated depreciation(856.9)(237.5)(51.8)(66.7)(1,212.9)
Property, plant and equipment, net$1,762.4 $462.1 $114.0 $29.3 $2,367.8 
Depreciation expense for the three months ended March 31, 2021$50.4 $10.7 $3.0 $2.5 $66.6 
  Refining Logistics Retail Corporate,
Other and Eliminations		 Consolidated
Property, plant and equipment $2,561.6
 $681.0
 $163.9
 $108.4
 $3,514.9
Less: Accumulated depreciation (713.5) (207.2) (42.4) (68.4) (1,031.5)
Property, plant and equipment, net $1,848.1
 $473.8
 $121.5
 $40.0
 $2,483.4
Depreciation expense for the three months ended June 30, 2020 $43.2
 $8.6
 $3.1
 $2.8
 $57.7
Depreciation expense for the six months ended June 30, 2020 $78.8
 $14.9
 $5.8
 $9.0
 $108.5

In accordance with ASC 360, Property, Plant and Equipment ("ASC 360"), Delek evaluates the realizability of property, plant and equipment as events occur that might indicate potential impairment. There were no indicators of impairment related to our property, plant and equipment as of June 30, 2020March 31, 2021 (see Note 1 for further discussion on the impact of COVID-19 Pandemic and OPEC Production Disputes)Pandemic).



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Notes to Condensed Consolidated Financial Statements (Unaudited)


Note 3 - Earnings (Loss) Per Share
Basic earnings per share (or "EPS") is computed by dividing net income (loss) by the weighted average common shares outstanding. Diluted earnings per share is computed by dividing net income (loss), as adjusted for changes to income that would result from the assumed settlement of the dilutive equity instruments included in diluted weighted average common shares outstanding, by the diluted weighted average common shares outstanding. For all periods presented, we have outstanding various equity-based compensation awards that are considered in our diluted EPS calculation (when to do so would be dilutive), and is inclusive of awards disclosed in Note 15 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.
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Notes to Condensed Consolidated Financial Statements (Unaudited)
The following table sets forth the computation of basic and diluted earnings per share.
  Three Months Ended Six Months Ended
  June 30, June 30,
  2020
2019 2020 2019
Numerator:        
Numerator for EPS        
Income (loss) from continuing operations, net of tax $98.5
 $84.6
 $(208.5) $239.0
Less: Income from continuing operations attributed to non-controlling interest 10.8
 6.5
 18.2
 11.6
Numerator for basic and diluted EPS - attributable to Delek $87.7
 $78.1
 $(226.7) $227.4
         
Numerator for EPS - discontinued operations        
Loss from discontinued operations attributable to Delek $—
 $(0.8) $—
 $(0.8)
         
Denominator:        
Weighted average common shares outstanding (denominator for basic EPS) 73,547,582
 76,598,846
 73,492,656
 77,192,763
Dilutive effect of stock-based awards 480,461
 681,846
 —
 690,522
Weighted average common shares outstanding, assuming dilution (denominator for diluted EPS) 74,028,043
 77,280,692
 73,492,656
 77,883,285
         
EPS:        
Basic income (loss) per share:        
 Income (loss) from continuing operations $1.19
 $1.02
 $(3.08) $2.95
Loss from discontinued operations $—
 (0.01) $—
 (0.01)
Basic income (loss) per share $1.19
 $1.01
 $(3.08) $2.94
Diluted income (loss) per share:        
Income (loss) from continuing operations $1.18
 $1.01
 $(3.08) $2.92
Loss from discontinued operations $—
 (0.01) $—
 (0.01)
Diluted income (loss) per share $1.18
 $1.00
 $(3.08) $2.91
         
The following equity instruments were excluded from the diluted weighted average common shares outstanding because their effect would be antidilutive:        
Antidilutive stock-based compensation (because average share price is less than exercise price) 3,922,290
 1,927,150
 3,328,789
 2,153,411
Antidilutive due to loss —
 —
 372,220
 —
Total antidilutive stock-based compensation 3,922,290
 1,927,150
 3,701,009
 2,153,411




Three Months Ended
March 31,
 20212020
Numerator:
Numerator for EPS
Net loss$(91.3)$(307.0)
Less: Income attributed to non-controlling interest7.3 7.4 
Numerator for basic and diluted EPS attributable to Delek$(98.6)$(314.4)
Denominator:
Weighted average common shares outstanding (denominator for basic EPS)73,803,772 73,437,730 
Dilutive effect of stock-based awards0 0 
Weighted average common shares outstanding, assuming dilution (denominator for diluted EPS)73,803,772 73,437,730 
EPS:
Basic loss per share$(1.34)$(4.28)
Diluted loss per share$(1.34)$(4.28)
The following equity instruments were excluded from the diluted weighted average common shares outstanding because their effect would be antidilutive:
Antidilutive stock-based compensation (because average share price is less than exercise price)634,006 3,684,935 
Antidilutive due to loss2,733,056 433,488 
Total antidilutive stock-based compensation3,367,062 4,118,423 
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Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 4 - Delek Logistics
Delek Logistics is a publicly traded limited partnership that was formed by Delek in 2012 to own, operate, acquire and construct crude oil and refined products logistics and marketing assets. A substantial majority of Delek Logistics' assets are integral to Delek’s refining and marketing operations. As of June 30, 2020,March 31, 2021, we owned a 69.1%an 80.0% interest in Delek Logistics, consisting of 20,745,86834,745,868 common limited partner units (representing a 70.5% interest), and a 94.8% interest in Delek Logistics GP, LLC, which owns the entire 2.0%non-economic general partner interest (consisting of 600,678 general partner units) in Delek Logistics as well as all of the incentive distribution rights.
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 condensed consolidated statements of income and in non-controlling interest in subsidiaries in the accompanying condensed consolidated balance sheets.
On August 13, 2020, Delek Logistics completed a transaction to eliminate the incentive distribution rights ("IDRs") held by Delek Logistics GP, LLC, the general partner, and convert the economic general partner interest into a non-economic general partner interest in exchange for total consideration consisting of $45.0 million cash and 14.0 million newly issued common limited partner units. Contemporaneously, we repurchased the 5.2% ownership interest in the general partner from affiliates, who are also members of the general partner's management and board of directors, for $23.1 million, increasing our ownership interest in the general partner to 100.0%.
As a result of these transactions, the non-controlling interest in our consolidated balance sheets decreased by $50.8 million, with a $37.2 million increase to additional paid-in capital which is net of $11.5 million related to deferred income taxes and $2.1 million of transaction costs, none of which was recognized during the first quarter of 2020.
In August 2020, Delek Logistics filed a shelf registration statement, which subsequently became effective, with the SEC for the proposed re-sale or other disposition from time to time by Delek of up to 14.0 million common limited partner units representing our limited partner interests in Delek Logistics. No units were sold as of March 31, 2021.
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.
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Notes to Condensed Consolidated Financial Statements (Unaudited)
Delek Logistics is a variable interest entity,VIE, as defined under GAAP, and is consolidated into our condensed 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 as presented below are included in the condensed consolidated balance sheets of Delek (unaudited, in millions).

 June 30,
2020		 December 31,
2019
   
ASSETS    
Cash and cash equivalents $16.2
 $5.5
Accounts receivable 15.9
 13.2
Accounts receivable from related parties 8.8
 —
Inventory 2.1
 12.6
Other current assets 0.5
 2.3
Property, plant and equipment, net 473.7
 295.0
Equity method investments 255.3
 247.0
Operating lease right-of-use assets 18.9
 3.7
Goodwill 12.2
 12.2
Intangible assets, net 163.1
 146.6
Other non-current assets 7.0
 6.3
Total assets $973.7
 $744.4
LIABILITIES AND DEFICIT    
Accounts payable $1.8
 $12.5
Accounts payable to related parties —
 8.9
Current portion of operating lease liabilities 5.8
 1.4
Accrued expenses and other current liabilities 10.3
 12.2
Long-term debt 995.2
 833.1
Asset retirement obligations 5.8
 5.6
Deferred tax liabilities 1.2
 0.2
Operating lease liabilities, net of current portion 13.1
 2.3
Other non-current liabilities 18.8
 19.3
Deficit (78.3) (151.1)
Total liabilities and deficit $973.7
 $744.4

March 31, 2021December 31, 2020
ASSETS  
Cash and cash equivalents$13.4 $4.2 
Accounts receivable12.3 15.7 
Accounts receivable from related parties0 5.9 
Inventory1.9 3.1 
Other current assets0.5 0.4 
Property, plant and equipment, net462.1 464.8 
Equity method investments251.4 253.7 
Operating lease right-of-use assets24.8 24.2 
Goodwill12.2 12.2 
Intangible assets, net158.8 160.1 
Other non-current assets11.5 12.1 
Total assets$948.9 $956.4 
LIABILITIES AND DEFICIT
Accounts payable$4.2 $6.7 
Accounts payable to related parties4.5 0 
Current portion of operating lease liabilities8.4 8.7 
Accrued expenses and other current liabilities15.7 12.9 
Long-term debt983.4 992.3 
Asset retirement obligations6.1 6.0 
Deferred tax liabilities0.7 0.6 
Operating lease liabilities, net of current portion16.3 15.4 
Other non-current liabilities21.0 22.1 
Deficit(111.4)(108.3)
Total liabilities and deficit$948.9 $956.4 

Effective May 1, 2020, Delek through its wholly owned subsidiaries Lion Oil Company, LLC (“Lion Oil”) and Delek Refining, Ltd. (“Delek Refining”) contributed certain leased and owned tractors and trailers and related assets used in the provision of trucking and transportation services for crude oil, petroleum and certain other products throughout Arkansas, Oklahoma and Texas to Delek Trucking, LLC (“Delek Trucking”), a direct wholly owned subsidiary of Lion Oil. Following this contribution, Lion Oil sold all of the issued and outstanding membership interests in Delek Trucking (the “Acquisition”“Trucking Acquisition”) to DKL Transportation, LLC (“DKL Transportation”), a wholly owned subsidiary of Delek Logistics. Promptly following the consummation of the Trucking Acquisition, Delek Trucking merged with and into DKL Transportation, with DKL Transportation continuing as the surviving entity. Total consideration for the Trucking Acquisition was approximately $48.0 million in cash, subject to certain post-closing adjustments,

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Notes to Condensed Consolidated Financial Statements (Unaudited)

financed primarily with borrowings underon the Delek Logistics’ revolving credit facility.Logistics Credit Facility (as defined in Note 8). In connection with the Trucking Acquisition, Delek Refining, Lion Oil and DKL Transportation entered into a Transportation Services Agreement pursuant to which DKL Transportation will gather, coordinate the pickup of, transport and deliver petroleum products for Delek Refining and Lion Oil, as well as provide ancillary services as requested. Prior periods have not been recast in our Note 2 - Segment Data, Note 2, as these assets did not constitute a business in accordance with ASU 2017-01, Clarifying the Definition of a Business("ASU 2017-01"), and the transaction was accounted for as an acquisition of assets between entities under common control.
Effective March 31, 2020, Delek Logistics, through its wholly-owned subsidiary DKL Permian Gathering, LLC, acquired the Big Spring Gathering System, located in Howard, Borden and Martin Counties, Texas, from Delek, which included the execution of related commercial agreements. In connection with the closing of the transaction, Delek, Delek Logistics and various of their respective subsidiaries entered into a Throughput and Deficiency Agreement (the “T&D Agreement”). Under the T&D Agreement, Delek Logistics will operate and maintain the Big Spring Gathering System connecting our interests in and to certain crude oil production with the Delek Logistics' Big Spring, Texas terminal and provide gathering, transportation and other related services. The total consideration was subject to certain post-closing adjustments and was comprised of $100.0 million in cash and 5.0 million common units representing a limited partner interest in Delek Logistics. The cash component of this dropdown was financed with borrowings on the DKLDelek Logistics Credit Facility (as defined in Note 8).
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Notes to Condensed Consolidated Financial Statements (Unaudited)
Prior periods have not been recast in our Segment Data Note 2, as these assets did not constitute a business in accordance with ASU 2017-01 and the transaction was accounted for as an acquisition of assets between entities under common control.
Additionally, in March 2020, we purchased 451,822 of Delek Logistics limited partner units from an investor pursuant to a Common Unit Purchase Agreement between Delek Marketing & Supply, LLC and such investor. The purchase price of the units amounted to approximately $5.0 million. As a result of the transaction, our ownership in Delek Logistics' outstanding common limited partner units increased to 64.5% from 62.6%. Our ownership in Delek Logistics' common limited partner units was further increased to 70.5% as a result of the issuance of 5.0 million common units in connection with the Big Spring Gathering Assets Acquisition described above.

Note 5 - Equity Method Investments
Wink to Webster Pipeline
On July 30, 2019, we, through our wholly-owned direct subsidiary Delek US Energy, Inc. ("Delek Energy" or "Delek Member"), entered into a limited liability company agreement (the “LLCA”) and related agreements with multiple joint venture members of Wink to Webster Pipeline LLC (“WWP”). Pursuant to the LLCA, Delek Energy acquired a 15% ownership interest in WWP.WWP ("WWP Joint Venture"). WWP intends to construct and operate a crude oil pipeline system from Wink, Texas to Webster, Texas along with certain pipelines from Webster, Texas to other destinations in the Gulf Coast area. Pursuant to the LLCA, Delek Energy will be required to contribute its percentage interest of the applicable construction costs (including certain costs previously incurred by WWP) and, at the date we acquired our ownership interest, it iswas anticipated that Delek Energy’s capital contributions willwould total approximately $340 million to $380 million over the course of construction (expected to be two to three years). Construction of the crude oil pipeline system remains ongoing, where the main segment of the pipeline system connecting the Permian Basin to Houston, Texas was completed and began transporting crude oil in October 2020, and where other construction continues to progress. During the sixthree months ended June 30,March 31, 2020, we made capital contributions totaling $18.9 million. As of DecemberAdditionally, during the three months ended March 31, 2019, Delek's investment balance in WWP totaled $125.3 million.2021, we made additional capital contributions totaling $0.1 million based on capital calls received.
On February 21, 2020, we, through our wholly-owned direct subsidiary Delek Energy, entered into the W2W Holdings LLC ("HoldCo") Agreement with MPLX Operations LLC ("MPLX") (collectively, with its wholly-owned subsidiaries, the "WWP Project Financing Joint Venture" or the "WWP Project Financing JV"). The WWP Project Financing JV was created for the specific purpose of obtaining financing through its wholly-owned subsidiary, W2W Finance LLC, to fund the majority of our combined capital calls resulting from and occurring during the construction period of the pipeline system under the WWP Joint Venture, and to service that debt. In connection with the arrangement, both Delek Energy and MPLX contributed their respective 15% ownership interests to the WWP Project Financing JV as collateral for and in service of the related project financing. Accordingly, distributions received from WWP through the WWP Project Financing JV will first be applied in service of the related project financing debt, with excess distributions being made to the members of the WWP Project Financing JV as provided for in the W2W Holdings LLC Agreement and as allowed under the project financing debt. The obligations of the members under the W2W Holdings LLC Agreement are guaranteed by the parents of the members of the WWP Project Financing JV.
The Company evaluated Delek Member'sEnergy's investment in HoldCoW2W Holdings LLC ("HoldCo") and determined that HoldCo is a variable interest entity.VIE. The Company determined it is not the primary beneficiary since it does not have the power to direct activities that most significantly impact HoldCo. The Company does not hold a controlling financial interest in HoldCo because no single party has the power to direct the activities that most significantly impact HoldCo’s economic performance since power to make the decisions about the significant activities is shared equally with MPLX and all significant decisions require unanimous consent of the Boardboard of Directors.directors of HoldCo. The Company accounts for its investment in HoldCo using the equity method of accounting due to its significant influence with its 50% membership interest.
The Company's maximum exposure to any losses incurred by HoldCo is limited to its investment. As of June 30, 2020,March 31, 2021, except for the guarantee of member obligations under the W2W Holdings LLC Agreement, the Company does not have other existing guarantees with or to HoldCo, or any third-party work contracted with it.
As of June 30,March 31, 2021 and December 31, 2020, , Delek's investment balance in WWP Project Financing Joint Venture totaled $73.0 million.$66.4 million and $66.6 million, respectively, and is included as part of total assets in corporate, other and eliminations in our segment disclosure. During the sixthree months ended June 30,March 31, 2020, we received distributions of $69.3 million from WWP Project Financing Joint Venture to return excess contributions made. In addition, we recognized a loss on the investment totaling $0.9$0.3 million and $2.0$1.1 million for the three and six months ended June 30,March 31, 2021 and 2020,

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Notes to Condensed Consolidated Financial Statements (Unaudited)

respectively. This investment is accounted for using the equity method and is included as part of total assets in corporate, other and eliminations in our segment disclosure.
Delek Logistics Investments
In May 2019, Delek Logistics, through its wholly owned indirect subsidiary DKL Pipeline, LLC (“DKL Pipeline”), entered into a Contribution and Subscription Agreement (the “Contribution Agreement”) with Plains Pipeline, L.P. (“Plains”) and Red River Pipeline Company LLC (“Red River”). Pursuant to the Contribution Agreement, DKL Pipeline contributed $124.7 million, substantially all of which was financed under the Delek Logistics Credit Facility (as defined in Note 8), to Red River in exchange for a 33% membership interest in Red River and DKL Pipeline’s admission as a member of Red River (the "Red River Pipeline Joint Venture"). Red River owns a 16-inch crude oil pipeline running from Cushing, Oklahoma to Longview, Texas, with anTexas. In August 2020, Red River completed a planned expansion project planned to increase the pipeline capacity which is expected to be completed during the third quarter ofcommenced operations on October 1, 2020. Delek Logistics contributed an additional $3.5 million related to such
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Notes to Condensed Consolidated Financial Statements (Unaudited)
expansion project in May 2019 and during 2020 made additional capital contributions of $12.2 million based on capital calls received. During the sixthree months ended June 30, 2020,March 31, 2021, we made additional capital contributions totaling $10.5$1.4 million based on capital calls received. As of June 30, 2020March 31, 2021 and December 31, 2019,2020, Delek's investment balance in Red River totaled $142.0$140.1 million and $131.0$141.8 million, respectively, and werespectively. We recognized income on the investment totaling $2.9$2.7 million and $4.7$1.8 million for the three and six months ended June 30,March 31, 2021 and 2020, 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 2 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 RIORio Pipeline LLC which operates the other pipeline system (the "RIO"Rio Pipeline"). As of June 30, 2020March 31, 2021 and December 31, 2019,2020, Delek Logistics' investment balances in these joint ventures totaled $113.3$111.8 million and $116.0$111.9 million, respectively, and were accounted for using the equity method. We recognized income on these investments totaling $3.5$1.8 million and $7.3$3.8 million for the three and six months ended June 30,March 31, 2021 and 2020, respectively and $2.2 million and $4.1 million for the three and six months ended June 30, 2019, respectively.
Other Investments
We have a 50% interest in a joint venture that owns an asphalt terminal located in Brownwood, Texas. As of June 30, 2020March 31, 2021 and December 31, 2019,2020, Delek's investment balance in this joint venture was $35.3$38.2 million and $30.7$39.3 million, respectively. We recognized income on this investment totaling $5.0$0.9 million and $5.5$0.4 million for the three and six months ended June 30,March 31, 2021 and 2020, respectively and $4.7 million and $5.2 million for the three and six months ended June 30, 2019, respectively. This investment is accounted for using the equity method and is included as part of total assets in corporate, other and eliminations in our segment disclosure.
Delek Renewables, LLC, a wholly-owned subsidiary of Delek, has a joint venture that owns, operates and maintains a terminal consisting of an ethanol unit train facility with an ethanol tank in North Little Rock, Arkansas. As of June 30, 2020March 31, 2021 and December 31, 2019,2020, Delek Renewables, LLC's investment balance in this joint venture was $3.7$4.2 million and $4.3$4.0 million, respectively, and was accounted for using the equity method. We recognized income on this investment totaling $0.2 million for both the three months ended March 31, 2021 and 2020. The investment in this joint venture is reflected in the refining segment.

Note 6 - Inventory
Crude oil, work in process, refined products, blendstocks and asphalt inventory for all of our operations, excluding the Tyler refinery and merchandise inventory in our retail segment, are stated at the lower of cost determined using FIFO basis or net realizable value. Cost of all inventory at the Tyler refinery is determined using the LIFO inventory valuation method and inventory is stated at the lower of cost or market.  Retail merchandise inventory consists of cigarettes, beer, convenience merchandise and food service merchandise and is stated at estimated cost as determined by the retail inventory method.
Carrying value of inventories consisted of the following (in millions):
  June 30,
2020		 December 31,
2019
Refinery raw materials and supplies $304.5
 $400.4
Refinery work in process 75.3
 109.1
Refinery finished goods 244.9
 397.5
Retail fuel 5.4
 7.3
Retail merchandise 21.3
 19.8
Logistics refined products 2.1
 12.6
Total inventories $653.5
 $946.7


March 31, 2021December 31, 2020
Refinery raw materials and supplies$528.0 $270.7 
Refinery work in process109.4 92.1 
Refinery finished goods363.1 327.1 
Retail fuel6.7 6.2 
Retail merchandise25.5 28.5 
Logistics refined products1.9 3.1 
Total inventories$1,034.6 $727.7 
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Notes to Condensed Consolidated Financial Statements (Unaudited)

At June 30, 2020,March 31, 2021, we recorded a pre-tax inventory valuation reserve of $77.0$10.7 million, $76.3$8.9 million of which related to LIFO inventory, due to a market price decline below our cost of certain inventory products. At December 31, 2019,2020, we recorded a pre-tax inventory valuation reserve of $1.7$31.1 million, $1.2$30.3 million of which related to LIFO inventory, which reversed in the first quarter of 20202021 due to the sale of inventory quantities that gave rise to the December 31, 20192020 reserve. We recognized a net reduction (increase) reduction in cost of materials and other in the accompanying condensed consolidated statements of income related to the change in pre-tax inventory valuation of $203.1$20.4 million and $(75.1)$(280.8) million for the three and six months ended June 30,March 31, 2021 and 2020, respectively, and $(0.6) million and $51.5 million for the three and six months ended June 30, 2019, respectively.

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Note 7 - Crude Oil Supply and Inventory Purchase Agreement
Delek has Supply and Offtake Agreements with J. Aron & Company ("J. Aron") in connection with its El Dorado, Big Spring and Krotz Springs refineries (collectively, the "Supply and Offtake Agreements"). Pursuant to the Supply and Offtake Agreements, (i) J. Aron agrees to sell to us, and we agree to buy from J. Aron, at market prices, crude oil for processing at these refineries and (ii) we agree to sell, and J. Aron agrees to buy, at market prices, certain refined products produced at these refineries. The Supply and Offtake Agreements also provide for the lease to J. Aron of crude oil and refined product storage facilities, and the identification of prospective purchasers of refined products on J. Aron’s behalf. At the inception of the Supply and Offtake Agreements, we transferred title to a certain number of barrels of crude and other inventories to J. Aron (the "Step-In"), and the Supply and Offtake Agreements require the repurchase of remaining inventory (including certain "Baseline Volumes") at the termination of those Agreements (the "Step-Out"). The Supply and Offtake Agreements are accounted for as inventory financing arrangements under the fair value election provided by ASC 815 Derivatives and Hedging ("ASC 815") and ASC 825, Financial Instruments ("ASC 825").
Barrels subject to the Supply and Offtake Agreements are as follows:
(in millions)El DoradoBig SpringKrotz Springs
Baseline Volumes pursuant to the respective Supply and Offtake Agreements2.0 0.8 1.3 
Barrels of inventory consigned under the respective Supply and Offtake Agreements as of March 31, 2021 (1)
3.4 1.3 1.4 
Barrels of inventory consigned under the respective Supply and Offtake Agreements as of December 31, 2020 (1)
4.0 1.3 1.2 
(in millions) El Dorado Big Spring Krotz Springs
Baseline Volumes pursuant to the respective Supply and Offtake Agreements 2.0
 0.8
 1.3
Barrels of inventory consigned under the respective Supply and Offtake Agreements as of June 30, 2020 (1)
 3.5
 1.6
 1.4
Barrels of inventory consigned under the respective Supply and Offtake Agreements as of December 31, 2019 (1)
 3.5
 2.0
 1.7
(1) Includes Baseline Volumes plus/minus over/short quantities.
(1)
Includes Baseline Volumes plus/minus over/short quantities.
The Supply and Offtake Agreements have certain termination provisions, which may include requirements to negotiate with third parties for the assignment to us of certain contracts, commitments and arrangements, including procurement contracts, commitments for the sale of product, and pipeline, terminalling, storage and shipping arrangements.
The Supply and Offtake Agreements were amended in December 2018 for Big Spring and in January 2019 for El Dorado and Krotz Springs so that the Baseline Step-Out Liabilities, as defined below, were based upon a fixed price. As a result, we recorded gains on the change in fair value resulting from the modification in cost of materials and other in the periods in which the amendments occurred, including a gain of $7.6 million which was recognized in the first quarter of 2019. As a result of these amendments, the subsequent changes in fair value of the Baseline Step-Out Liabilities were recorded in interest expense.
In January 2020, we amended our three Supply and Offtake Agreements so that 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") would bewas based on market-indexed prices subject to commodity price risk. As a result of the amendment, such Baseline Step-Out Liabilities will continuecontinued to be recorded at fair value under the fair value election provided by ASC 815 and ASC 825, where the fair value will now reflectreflected changes in commodity price risk rather than interest rate risk with subsequent changes in fair value being recorded in cost of materials and other. We recognized a loss in the first quarter of 2020 of $1.5 million on the change in fair value resulting from the modification.
In April 2020, we amended and restated our three Supply and Offtake Agreements to renew and extend the terms to December 30, 2022, with J. Aron having the sole discretion to further extend to May 30, 2025 by giving at least 6 months prior notice to the current maturity date. As part of this amendment, there were changes to the underlying market index, annual fee, the crude purchase fee, crude roll fees and timing of cash settlements related to periodic price adjustments (the "Periodic Price Adjustments"). The Baseline Step-Out Liabilities continue to be recorded at fair value under the fair value election included under ASC 815 and ASC 825. The Baseline Step-Out Liabilities have a floating component whose fair value reflects changes to commodity price risk with changes in fair value recorded in cost of materials and other and a fixed component whose fair value reflects changes to interest rate risk with changes in fair value recorded in interest expense. There was no amendment date change in fair value resulting from the modification. The Baseline Step-Out Liabilities are reflected as non-current liabilities on our consolidated balance sheet to the extent that they are not contractually due within twelve months.
Pursuant to the Periodic Price Adjustments provision in the Supply and Offtake Agreements, the Company may be required to pay down all or a portion of the fixed component of the Baseline Step-Out Liabilities or may receive additional proceeds depending on the change in fair value of the inventory collateral subject to a threshold at certain specified Periodicperiodic pricing dates (the "Periodic Pricing Dates,Dates"), which occur on October 1st and May 1st, annually, not to extend beyond expiration of the Supply and Offtake Agreements. Additionally, at the Periodic Pricing Dates, if a Periodic Price Adjustment is triggered, the prospective pricing underlying the fixed component of the Baseline Step-Out Liabilities will be adjusted to reflect either the pay-down or the incremental proceeds, accordingly. On October 1, 2020, the provision was triggered and a paydown amounting to $20.8 million was made to J. Aron on October 30, 2020. The prospective pricing underlying the fixed component of the Baseline Step-Out liabilities was adjusted accordingly to reflect this payment, resulting in a reduction to the fixed differential component of our long-term Supply and Offtake Obligation totaling $20.8 million and a prospective contractual reset of the fixed differentials subject to future Periodic Price Adjustments. Contemporaneous with the payment, J. Aron separately refunded to us the $10.0 million of deferred additional monthly fees. As of June 30,both March 31, 2021 and December 31, 2020, the fixed component of the Baseline Step-Out Liabilities subject to the Periodic Price Adjustments amounted to approximately $58.8$33.1 million. All or some portion of that amount may
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become due or payable in periods occurring within twelve months, if Periodic Price Adjustments are triggered in October 2020 and May 2021.

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on the Periodic Pricing Dates.
Monthly activity resulting in over and short volumes continue to be valued using market-indexed pricing, and are included in current liabilities (or receivables) on our condensed consolidated balance sheet.
Net balances payable (receivable) under the Supply and Offtake Agreements were as follows as of the balance sheet dates:
(in millions)El DoradoBig SpringKrotz SpringsTotal
Balances as of March 31, 2021:
Baseline Step-Out Liability$136.8 $60.1 $90.2 $287.1 
Revolving over/short inventory financing liability85.0 31.7 6.9 123.6 
Total Obligations Under Supply and Offtake Agreements221.8 91.8 97.1 410.7 
Less: Current portion85.0 31.7 6.9 123.6 
Obligations Under Supply and Offtake Agreements - Noncurrent portion$136.8 $60.1 $90.2 $287.1 
Other current payable (receivable) for monthly activity true-up$1.4 $4.7 $(7.0)$(0.9)
(in millions) El Dorado Big Spring Krotz Springs Total
Balances as of June 30, 2020:        
Baseline Step-Out Liability $97.9
 $48.0
 $69.1
 $215.0
Revolving over/short inventory financing liability 63.6
 30.7
 4.7
 99.0
Total Obligations Under Supply and Offtake Agreements 161.5
 78.7
 73.8
 314.0
Less: Current portion 63.6
 30.7
 4.7
 99.0
Obligations Under Supply and Offtake Agreements - Noncurrent portion $97.9
 $48.0
 $69.1
 $215.0
Other current payable (receivable) for monthly activity true-up $7.0
 $(8.8) $7.4
 $5.6
(in millions) El Dorado Big Spring Krotz Springs Total
Balances as of December 31, 2019:        
Baseline Step-Out Liability $125.5
 $57.2
 $87.6
 $270.3
Revolving over/short inventory financing liability 93.0
 73.5
 40.5
 207.0
Total Obligations Under Supply and Offtake Agreements 218.5
 130.7
 128.1
 477.3
Less: Current portion 218.5
 73.5
 40.5
 332.5
Obligations Under Supply and Offtake Agreements - Noncurrent portion $—
 $57.2
 $87.6
 $144.8
Other current receivable for monthly activity true-up $(16.4) $(3.1) $(3.5) $(23.0)

(in millions)El DoradoBig SpringKrotz SpringsTotal
Balances as of December 31, 2020:
Baseline Step-Out Liability$106.3 $47.9 $70.7 $224.9 
Revolving over/short inventory financing liability (receivable)102.0 25.3 (4.5)122.8 
Total Obligations Under Supply and Offtake Agreements208.3 73.2 66.2 347.7 
Less: Current portion (1)
102.0 25.3 (4.5)122.8 
Obligations Under Supply and Offtake Agreements - Noncurrent portion$106.3 $47.9 $70.7 $224.9 
Other current payable for monthly activity true-up$6.6 $7.0 $0 $13.6 

(1) Current portion for Krotz Springs includes $1.9 million of current portion of obligations under Supply and Offtake Agreements and $6.4 million of current assets presented in our condensed consolidated balance sheet.
The Supply and Offtake Agreements require payments of fixed annual fees which are factored into the interest rate yield under the fair value accounting model. Recurring cash fees paid during the periods presented were as follows:
(in millions)El DoradoBig SpringKrotz SpringsTotal
Recurring cash fees paid during the three months ended March 31, 2021$2.4 $0.7 $1.1 $4.2 
Recurring cash fees paid during the three months ended March 31, 2020$3.2 $1.0 $1.0 $5.2 
(in millions) El Dorado Big Spring Krotz Springs Total
Recurring cash fees paid during the three months ended June 30, 2020 $2.7
 $1.1
 $1.0
 $4.8
Recurring cash fees paid during the three months ended June 30, 2019 $3.2
 $1.5
 $2.6
 $7.3
Recurring cash fees paid during the six months ended June 30,2020 $5.9
 $2.1
 $2.0
 $10.0
Recurring cash fees paid during the six months ended June 30, 2019 $5.7
 $2.9
 $5.0
 $13.6
Interest expense recognized under the Supply and Offtake Agreements includes the yield attributable to recurring cash fees, one-time cash fees (e.g., in connection with amendments), as well as other changes in fair value, which may increase or decrease interest expense. Total interest expense incurred during the periods presented was as follows:
(in millions) El Dorado Big Spring Krotz Springs Total
Interest expense for the three months ended June 30, 2020 $2.7
 $1.1
 $1.0
 $4.8
Interest expense for the three months ended June 30, 2019 $4.1
 $1.7
 $2.9
 $8.7
Interest expense for the six months ended June 30, 2020 $6.3
 $5.2
 $2.4
 $13.9
Interest expense for the six months ended June 30, 2019 $7.3
 $1.6
 $6.0
 $14.9

(in millions)El DoradoBig SpringKrotz SpringsTotal
Interest expense for the three months ended March 31, 2021$2.4 $0.7 $1.1 $4.2 
Interest expense for the three months ended March 31, 2020$3.6 $4.1 $1.4 $9.1 
Reflected in interest expense areThere were losses totaling $3.9 million for the sixthree months ended June 30,March 31, 2020, and losses totaling $1.4 million and gains totaling $3.7 million for the three and six months ended June 30, 2019, respectively,reflected in interest expense related to the changes in fair value in the Baseline Step-Out Liabilities component of Obligations Under Supply and Offtake Agreements. There were 0 such gains or losses for the three months ended June 30, 2020.March 31, 2021.
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We maintained letters of credit under the Supply and Offtake Agreements as follows:

(in millions)El DoradoBig Spring and Krotz Springs
Letters of credit outstanding as of March 31, 2021$145.0 $10.0 
Letters of credit outstanding as of December 31, 2020$195.0 $10.0 
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(in millions)  El Dorado Big Spring and Krotz Springs
Letters of credit outstanding as ofJune 30, 2020 $170.0
 $10.0
Letters of credit outstanding as ofDecember 31, 2019 $180.0
 $44.0



Note 8 - Long-Term Obligations and Notes Payable
Outstanding borrowings, net of unamortized debt discounts and certain deferred financing costs, under Delek’s existing debt instruments are as follows (in millions):
March 31, 2021December 31, 2020
Revolving Credit Facility$50.0 $0 
Term Loan Credit Facility (1)
1,245.2 1,246.8 
Hapoalim Term Loan (2)
39.2 39.3 
Delek Logistics Credit Facility737.5 746.6 
Delek Logistics Notes (3)
245.9 245.7 
Reliant Bank Revolver50.0 50.0 
Promissory Notes0 20.0 
 2,367.8 2,348.4 
Less: Current portion of long-term debt and notes payable13.4 33.4 
 $2,354.4 $2,315.0 
  June 30, 2020 December 31, 2019
Revolving Credit Facility $100.0
 $30.0
Term Loan Credit Facility (1)
 1,250.3
 1,069.5
Delek Logistics Credit Facility 750.0
 588.4
Hapoalim Term Loan (2)
 39.4
 39.5
Delek Logistics Notes (3)
 245.2
 244.7
Reliant Bank Revolver 50.0
 50.0
Promissory Notes 20.0
 45.0
  2,454.9
 2,067.1
Less: Current portion of long-term debt and notes payable 33.4
 36.4
  $2,421.5
 $2,030.7

(1)Net of deferred financing costs of $2.7 million and $2.9 million and debt discount of $21.9 million and $23.3 million at March 31, 2021 and December 31, 2020, respectively.
(2)Net of deferred financing costs of $0.2 million and $0.2 million and debt discount of $0.1 million and $0.1 million at March 31, 2021 and December 31, 2020, respectively.
(3)Net of deferred financing costs of $3.1 million and $3.3 million and debt discount of $1.0 million and $1.0 million at March 31, 2021 and December 31, 2020, respectively.
(1)
Net of deferred financing costs of $3.2 million and $3.5 million and debt discount of $26.0 million and $12.5 million at June 30, 2020 and December 31, 2019, respectively.
(2)
Net deferred financing costs of $0.2 million and $0.3 million and debt discount of $0.2 million and $0.2 million at June 30, 2020 and December 31, 2019, respectively.
(3)
Net of deferred financing costs of $3.6 million and $4.0 million and debt discount of $1.2 million and $1.3 million at June 30, 2020 and December 31, 2019, respectively.
Delek Revolver and Term Loan
On March 30, 2018 (the "Closing Date"), Delek entered into (i) a new term loan credit agreement with Wells Fargo Bank, National Association, as administrative agent (the "Term Administrative Agent"), Delek, as borrower, certain subsidiaries of Delek, as guarantors, and the lenders from time to time party thereto, providing for a senior secured term loan facility in an amount of $700.0 million (the "Term Loan Credit Facility") and (ii) a second amended and restated credit agreement with Wells Fargo Bank, National Association, as administrative agent (the "Revolver Administrative Agent"), Delek, as borrower, certain subsidiaries of Delek, as guarantors, and the other lenders party thereto, providing for a senior secured asset-based revolving credit facility with commitments of $1.0 billion (the "Revolving Credit Facility" and, together with the Term Loan Credit Facility, the "New Credit Facilities").
The Revolving Credit Facility permits borrowings in Canadian dollars of up to $50.0 million. The Revolving Credit Facility also permits the issuance of letters of credit of up to $400.0 million, including letters of credit denominated in Canadian dollars of up to $10.0 million. Delek may designate restricted subsidiaries as additional borrowers under the Revolving Credit Facility.
The Term Loan Credit Facility was drawn in full for $700.0 million on the Closing Date at an original issue discount of 0.50%. Proceeds under the Term Loan Credit Facility, as well as proceeds of approximately $300.0 million in borrowings under the Revolving Credit Facility on the Closing Date, were used to repay certain indebtedness of Delek and its subsidiaries (the “Refinancing”), as well as certain fees, costs and expenses in connection with the closing of the New Credit Facilities, with any remaining proceeds held in cash. Proceeds of future borrowings under the Revolving Credit Facility willmay be used for working capital and general corporate purposes of Delek and its subsidiaries.

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Notes to Condensed Consolidated Financial Statements (Unaudited)

On May 22, 2019 (the "First Incremental Effective Date"), we amended the Term Loan Credit Facility agreement pursuant to the terms of the First Incremental Amendment to Term Loan Credit Agreement (the "Incremental Amendment"). Pursuant to the Incremental Amendment, the Company borrowed $250.0 million in aggregate principal amount of incremental term loans (the “Incremental Term Loans”) at an original issue discount of 0.75%, increasing the aggregate principal amount of loans outstanding under the Term Loan Credit Facility on the First Incremental Effective Date to $943.0 million.. On November 12, 2019 (the "Second Incremental Effective Date"), we amended the Term Loan Credit facility agreement pursuant to the terms of the Second Incremental Amendment to the Term Loan Credit Agreement (the "Second Incremental Amendment") and borrowed $150.0 million in aggregate principal amount of incremental term loans (the "Incremental Loans") at an original issue discount of 1.21%, increasing the aggregate principal amount of loans outstanding under the Term Loan Credit Facility on the Second Incremental Effective Date to $1,088.3 million.. The terms of the Incremental Term Loans and Incremental Loans are substantially identical to the terms applicable to the initial term loans under the Term Loan Credit Facility borrowed in March 2018. There are no restrictions on the Company's use of the proceeds of the Incremental Term Loans and Incremental Loans. The proceeds may be used for (i) reducing utilizations under the Revolving Credit Facility, (ii) general corporate purposes and (iii) paying transaction fees and expenses associated with the incremental amendments.
On May 19, 2020, we amended the Term Loan Credit Facility agreement and borrowed $200.0 million in aggregate principal amount of incremental term loans (the “Third Incremental Term Loan”) at an original issue discount of 7.00%. The Third Incremental Term Loan constitutes a separate class of term loanloans (the "Class B Loan"Loans") under the Term Loan Credit Facility from those initially borrowed in March 2018 and the incremental term loans borrowed in May 2019 and November 2019 (collectively, the "Class A Loans"). Delek will be required to pay a make-whole prepayment fee if the Third Incremental Term Loan is prepaid pursuant to an optional prepayment, in connection with a non-permitted debt issuance or in connection with an acceleration within one year of the incurrence of the Third Incremental Term Loan. Delek may voluntarily prepay the outstanding Third Incremental Term LoansLoan at any time subject to customary “breakage”breakage costs with respect to LIBOR loans and subject to a prepayment premium of 1.0%1.00% in connection with certain customary repricing events that may occur during the period from the day after the first anniversary of the Third Incremental Term Loan through the second anniversary of the Third Incremental Term Loan. The other terms of the Third Incremental Term Loan are substantially identical to the terms applicable to the Class A Loans. The proceeds of the Third Incremental Term Loan may be used (i) for general corporate purposes and (ii) to pay transaction fees and expenses associated with the Third Incremental Term Loan.
Interest and Unused Line Fees
The interest rates applicable to borrowings under the Term Loan Credit Facility and the Revolving Credit Facility are based on a fluctuating rate of interest measured by reference to either, at Delek’s option, (i) a base rate, plus an applicable margin, or (ii) a reserve-adjusted LIBOR, plus an applicable margin (or, in the case of Revolving Credit Facility borrowings denominated in Canadian dollars, the Canadian dollar bankers' acceptances rate ("CDOR")). The initial applicable margin for all Term Loan Credit Facility borrowings was 1.50% per annum with respect to base rate borrowings and 2.50% per annum with respect to LIBOR borrowings. On October 26, 2018, Delek entered into an amendment to the Term Loan Credit Facility (the “First Amendment”) to reduce the margin on certain borrowings under the Term Loan Credit Facility and incorporate certain other changes. The First Amendment decreased the applicable margins for Class A Loans under (i) Base Rate Loans from 1.50%by 0.25% to 1.25% and (ii) LIBOR Rate Loans from 2.50%by 0.25% to 2.25%, as such terms are defined in the Term Loan Credit Facility. Class B Loans incurred under the Third Incremental Term Loan bear interest at a rate that is determined, at the Company’s election, at LIBOR or at base rate, in each case, plus an applicable margin of 5.50% with respect to LIBOR borrowings and 4.50% with respect to base rate borrowings. Additionally, Class B loans that are LIBOR borrowings are subject to a minimum LIBOR rate floor of 1.00%.
The initial applicable margin for Revolving Credit Facility borrowings was 0.25% per annum with respect to base rate borrowings and 1.25% per annum with respect to LIBOR and CDOR borrowings, and the applicable margin for such borrowings after September 30, 2018 is based on Delek’s excess availability as determined by reference to a borrowing base, ranging from 0.25% to 0.75% per annum with respect to base rate borrowings and from 1.25% to 1.75% per annum with respect to LIBOR and CDOR borrowings.
In addition, the Revolving Credit Facility requires Delek to pay an unused line fee on the average amount of unused commitments thereunder in each quarter, which the fee is at a rate of 0.25% or 0.375% per annum, depending on average commitment usage for such quarter. As of June 30, 2020,March 31, 2021, the unused line fee was 0.375% per annum.
Maturity and Repayments
The Revolving Credit Facility will mature and the commitments thereunder will terminate on March 30, 2023. The Term Loan Credit Facility matures on March 30, 2025 and requires scheduled quarterly principal payments on the last business day of the applicable quarter. Pursuant to the Incremental Amendment, quarterly payments increased from $1.75 million to $2.38 million. Pursuant to the Second Incremental Amendment, the quarterly payments increased to $2.75 million commencing with December 31, 2019.2019 on the Class A Loans. Additionally, the Term Loan Credit Facility requires prepayments by Delek with the net cash proceeds from certain debt incurrences, asset dispositions and insurance or condemnation events with respect to Delek’s assets, subject to certain exceptions, thresholds and reinvestment rights. The Term Loan Credit Facility also requires annual prepayments with a variable percentage of Delek’s excess cash flow, ranging from 50.0% to 0% depending on Delek’s consolidated fiscal year end secured net leverage ratio. The Third Incremental Term Loan requires quarterly payments on the Class B Loans of $0.5 million commencing June 30, 2020.

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Guarantee and Security
The obligations of the borrowers under the New Credit Facilities are guaranteed by Delek and each of its direct and indirect, existing and future, wholly-owned domestic subsidiaries, subject to customary exceptions and limitations, and excluding Delek Logistics Partners, LP, Delek Logistics GP, LLC, and each subsidiary of the foregoing (collectively, the "MLP Subsidiaries"). Borrowings under the New Credit Facilities are also guaranteed by DK Canada Energy ULC, a British Columbia unlimited liability company and a wholly-owned restricted subsidiary of Delek.
The Revolving Credit Facility is secured by a first priority lien over substantially all of Delek’s and each guarantor's receivables, inventory, renewable identification numbers ("RINs"), instruments, intercompany loan receivables, deposit and securities accounts and related books and records and certain other personal property, subject to certain customary exceptions (the "Revolving Priority Collateral"), and a second priority lien over substantially all of Delek's and each guarantor's other assets, including all of the equity interests of any subsidiary held by Delek or any guarantor (other than equity interests in certain MLP Subsidiaries) subject to certain customary exceptions, but excluding real property (such real property and equity interests, the "Term Priority Collateral").
The Term Loan Credit Facility is secured by a first priority lien on the Term Priority Collateral and a second priority lien on the Revolving Priority Collateral, all in accordance with an intercreditor agreement between the Term Administrative Agent and the Revolver Administrative Agent and acknowledged by Delek and the subsidiary guarantors. Certain excluded assets are not included in the Term Priority Collateral and the Revolving Priority Collateral.
Additional Information
At June 30, 2020,March 31, 2021, the weighted average borrowing rate under the Revolving Credit Facility was 3.50% and was comprised entirely of a base rate borrowing, and the principal amount outstanding thereunder was $100.0$50.0 million. Additionally, there were letters of credit issued of approximately $204.6$314.6 million as of June 30, 2020March 31, 2021 under the Revolving Credit Facility. Unused credit commitments under the Revolving Credit Facility, as of June 30, 2020,March 31, 2021, were approximately $695.4$635.4 million.
At June 30, 2020,March 31, 2021, the weighted average borrowing rate under the Term Loan Credit Facility was approximately 3.06%3.00% comprised entirely of LIBOR borrowings, and the principal amount outstanding thereunder was $1,279.5$1,269.8 million. As of June 30, 2020,March 31, 2021, the effective interest rate related to the Term Loan Credit Facility was 3.44%3.61%.
Delek Hapoalim Term Loan
On December 31, 2019, Delek entered into a term loan credit and guaranty agreement (the "Agreement") with Bank Hapoalim B.M. ("BHI") as the administrative agent. Pursuant to the Agreement, on December 31, 2019, Delek borrowed $40.0 million (the "BHI Term Loan"). The interest rate under the Agreement is equal to LIBOR plus a margin of 3.00%. The Agreement has a current maturity of December 31, 2022 and requires quarterly loan amortization payments of $0.1 million, commencing March 31, 2020. Proceeds may be used for general corporate purposes. The Agreement has an accordion feature that allows increasing the term loan to maximum size of $100.0 million, subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent. Any such additional borrowings must be completed by December 31, 2021. On December 30, 2020, we amended the BHI Term Loan to modify one of the required quarterly financial covenant metrics; there were no other changes as a result of this amendment.
At June 30, 2020,March 31, 2021, the weighted average borrowing rate under the term loan was approximately 3.18%3.11% comprised entirely of a LIBOR borrowing and the principal amount outstanding thereunder was $39.8$39.5 million. As of June 30, 2020,March 31, 2021, the effective interest rate related to the BHI Term Loan was 3.61%3.54%.
Delek Logistics Credit Facility
Prior to its amendment and restatement on September 28, 2018, Delek Logistics had a $700.0 million senior secured revolving credit agreement with Fifth Third Bank ("Fifth Third"), as administrative agent, and a syndicate of lenders (the "2014 Facility"). On September 28, 2018, Delek Logistics and all of its subsidiaries entered into a third amended and restated senior secured revolving credit agreement with Fifth Third Bank ("Fifth Third") as administrative agent and a syndicate of lenders (hereafter, the "Delek Logistics Credit Facility"). Under the terms of the Delek Logistics Credit Facility, among other things, the with lender commitments were increased from $700.0 million to $850.0of 850.0 million. The Delek Logistics Credit Facility also contains an accordion feature whereby Delek Logistics can increase the size of the credit facility to an aggregate of $1.0 billion, subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent.
The obligations under the Delek Logistics Credit Facility remain secured by first priority liens on substantially all of Delek Logistics' tangible and intangible assets. Additionally, a subsidiary of Delek provided a limited guaranty of Delek Logistics' obligations under the Delek Logistics Credit Facility. The guaranty was (i) limited to an amount equal to the principal amount, plus unpaid and accrued interest, of a promissory note made by Delek in favor of the subsidiary guarantor (the "Holdings Note") and (ii) secured by the subsidiary guarantor's pledge of the Holdings Note to the Delek Logistics Credit Facility lenders. Effective March 30, 2020, the limited guaranty and pledge of the Holdings Note was terminated pursuant to a guaranty and pledge release approved by the required lenders under the Delek Logistics Credit Facility.
The Delek Logistics Credit Facility has a maturity date of September 28, 2023. Borrowings under the Delek Logistics Credit Facility bear interest at either a U.S. dollar prime rate, Canadian dollar prime rate, LIBOR, or a CDOR rate, in each case plus applicable margins, at the

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Notes to Condensed Consolidated Financial Statements (Unaudited)

election of the borrowers and as a function of draw down currency. The applicable margin in each case and the fee payable for the unused revolving commitments vary based upon Delek Logistics' most recent total leverage ratio calculation delivered to the lenders, as called for and defined under the terms of the Delek Logistics Credit Facility. At June 30, 2020,March 31, 2021, the weighted average borrowing rate was approximately 2.78%2.45%. Additionally, the Delek Logistics Credit Facility requires Delek Logistics to pay a leverage ratio dependent quarterly fee on the average unused revolving commitment. As of June 30, 2020,March 31, 2021, this fee was 0.40%0.35% on an annualized basis.
As
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Notes to Condensed Consolidated Financial Statements (Unaudited)
In connection with the elimination of June 30,IDRs in August 2020, Delek Logistics entered into a First Amendment to the Delek Logistics Credit Facility which, among other things, permitted the transfer of cash and equity consideration for the elimination of IDRs. It also modified the total leverage ratio and the senior leverage ratio (each as defined in the Delek Logistics Credit Facility) calculations to reduce the total funded debt (as defined in the Delek Logistics Credit Facility) component thereof by the total amount of unrestricted consolidated cash and cash equivalents on the balance sheet of the Delek Logistics and its subsidiaries up to $20.0 million.

As of March 31, 2021, Delek Logistics had $750.0$737.5 million of outstanding borrowings under the Delek Logistics Credit Facility, with no letters of credit in place. Unused credit commitments under the Delek Logistics Credit Facility, as of June 30, 2020,March 31, 2021, were $100.0$112.5 million.
Delek Logistics Notes
On May 23, 2017, Delek Logistics and Delek Logistics Finance Corp. (collectively, the “Issuers”) issued $250.0 million in aggregate principal amount of 6.75% senior notes due 2025 (the “Delek Logistics Notes”) at a discount. The Delek Logistics Notes are general unsecured senior obligations of the Issuers. The Delek Logistics Notes are unconditionally guaranteed jointly and severally on a senior unsecured basis by Delek Logistics' existing subsidiaries (other than Delek Logistics Finance Corp., the "Guarantors") and will be unconditionally guaranteed on the same basis by certain of Delek Logistics' future subsidiaries. The Delek Logistics Notes rank equal in right of payment with all existing and future senior indebtedness of the Issuers, and senior in right of payment to anyfuture subordinated indebtedness of the Issuers. Interest on theDelek Logistics Delek Logistics Notes is payable semi-annually in arrears on each May 15 and November 15, commencing November 15, 2017.
In May 2018, the Delek Logistics Notes were exchanged for new notes with terms substantially identical in all material respects with the Delek Logistic Notes except the new notes do not contain terms with respect to transfer restrictions.
All or part of the Delek Logistics Notes are currently redeemable, subject to certain conditions and limitations, at a redemption price of 105.063% of the redeemed principal, plus accrued and unpaid interest, if any. Beginning on May 15, 2020,2021, the Issuers may, subject to certain conditions and limitations, redeem all or part of the Delek Logistics Notes, at a redemption price of 105.063%103.375% of the redeemed principal for the twelve-month period beginning on May 15, 2020, 103.375% for the twelve-month period beginning on May 15, 2021, 101.688% for the twelve-month period beginning on May 15, 2022, and 100.00% beginning on May 15, 2023 and thereafter, plus accrued and unpaid interest, if any.
In the event of a change of control, accompanied or followed by a ratings downgrade within a certain period of time, subject to certain conditions and limitations, the Issuers will be obligated to make an offer for the purchase of the Delek Logistics Notes from holders at a price equal to 101% of the principal amount thereof, plus accrued and unpaid interest.
In May 2018, the Delek Logistics Notes were exchanged for new notes with terms substantially identical in all material respects with the 2025 Notes except the new notes do not contain terms with respect to transfer restrictions.
As of June 30, 2020,March 31, 2021, we had $250.0 million in outstanding principal amount under the Delek Logistics Notes. As of June 30, 2020,Notes, and the effective interest rate related to the Delek Logistics Notes was 7.22%7.25%.
Reliant Bank Revolver
Delek has an unsecured revolving credit agreement with Reliant Bank (the "Reliant Bank Revolver"). On December 16, 2019, we amended the Reliant Bank Revolver to extend the maturity date from June 28, 2020 to June 30, 2022, reduce the fixed interest rate from 4.75% to 4.50% per annum and increase the revolver commitment amount from $30.0 million to $50.0 million. There were no other significant changes to the agreement in connection with this amendment. On December 9, 2020, we amended the Reliant Bank Revolver to modify one of the required quarterly financial covenant metrics; there were no other changes as a result of this amendment. The revolving credit agreement requires us to pay a quarterly fee of 0.50% on an annualized basis on the average unused revolving commitment. As of June 30, 2020,March 31, 2021, we had $50.0 million outstanding and had 0 unused credit commitments under the Reliant Bank Revolver.
Promissory Notes
Delek hashad 4 notes payable (the "Promissory Notes") with various assignees of Alon Israel Oil Company, Ltd., the holder of a predecessor consolidated promissory note, which bearbore interest at a fixed rate of 5.50% per annum and which, collectively, requirerequired annual principal amortization payments of $25.0 million to be made each January through 2020, followed bywith a final principal amortization payment of $20.0 million which was paid at maturity on January 4, 2021. As of June 30, 2020, a total principal amount of $20.0 million was outstanding under the Promissory Notes.
Restrictive Covenants
Under the terms of our Revolving Credit Facility, Term Loan Credit Facility, Delek Logistics Credit Facility, Delek Logistics Notes, Reliant Bank Revolver and BHI Agreement, we are required to comply with certain usual and customary financial and non-financial covenants. The terms and conditions of the Revolving Credit Facility include periodic compliance with a springing minimum fixed charge coverage ratio financial covenant if excess availability under the revolver borrowing base is below certain thresholds, as defined in the credit agreement. The Term Loan Credit Facility does not have any financial maintenance covenants. We believe we were in compliance with all covenant requirements under each of our credit facilities as of June 30, 2020.March 31, 2021.
Certain of our debt facilities contain limitations on the incurrence of additional indebtedness, making of investments, creation of liens, dispositions and acquisitions of assets, and making of restricted payments and transactions with affiliates. These covenants may also limit the payment, in the form of cash or other assets, of dividends or other distributions, or the repurchase of shares with respect to the equity of certain of our subsidiaries. equity.
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Notes to Condensed Consolidated Financial Statements (Unaudited)
Additionally, some of our debt facilities limit our ability to make investments, including extensions of loans or advances to, or acquisitions of equity interests in, or guarantees of obligations of, certain other entities.

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Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 9 - 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 theour exposure to commodity price fluctuations of commodityon inventory above or below target levels at(where appropriate) within each of our segments;
•managing our exposure to commodity price risk associated with the purchase or sale of crude oil, feedstocksfeedstocks/intermediates and finished grade fuel products atwithin each of our segments;
•managing our exposure to market crack spread fluctuations;
•managing the cost of our credits for commitments required by the U.S. Environmental Protection Agency ("EPA") to blend biofuels into fuel products ("RINs Obligation") using future commitments to purchase or sell renewable identification numbers ("RINs")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 swapswaps or cap agreements,caps to achieve these objectives. Futures contracts are standardized agreements, traded on a futures exchange, to buy or sell thea commodity at a predetermined price and location at a specified future date. Options provide the right, but not the obligation to buy or sell the commodity at a specified price in the future. Commodity swapswaps 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 paymentpayment/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 pursuant to ASC 815815. If we elect the normal purchases and normal sales exception, such forward contracts are not accounted for as derivative instruments. Rather, such forward contractsinstruments but rather are accounted for under other applicable GAAP. ForwardCommodity forward contracts entered into for trading purposes that do not meet the normal purchases, normal sales exception are accounted for as derivative instruments are recorded at fair value with changes in fair value recognized in earnings in the period of change. As of June 30, 2020March 31, 2021 and December 31, 2019,2020, and for the three and six months ended June 30,March 31, 2021 and March 31, 2020, and June 30, 2019, all of our commodity fixed-price forward contracts that were accounted for as derivative instruments primarily consisted of contracts related to our Canadian crude trading operations. Since Canadian crude trading activity is not related to managing supply or pricing risk of the actual inventory that will be used in production, such unrealized and realized gains and losses are recognized in other operating income, net rather than cost of materials and other on the accompanying condensed consolidated statements of income.
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.
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 RINRINs 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 RINRINs commitment contracts are recorded in cost of materials and other on the condensed consolidated statements of income.
As of June 30, 2020,March 31, 2021, we do not believe there is any material credit risk with respect to the counterparties to any of our derivative contracts.
In accordance with ASC 815, certain of our commodity swap contracts have been designated as cash flow hedges and the change in fair value between the execution date and the end of period has been recorded in other comprehensive income. The fair value of these contracts is recognized in income in the same financial statement line item as hedged transaction at the time the positions are closed and the hedged transactions are recognized in income.
The following table presents the fair value of our derivative instruments as of June 30, 2020March 31, 2021 and December 31, 2019.2020. 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 10 for further information regarding the fair value of derivative instruments (in millions).

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Notes to Condensed Consolidated Financial Statements (Unaudited)

March 31, 2021December 31, 2020
Derivative TypeBalance Sheet LocationAssetsLiabilitiesAssetsLiabilities
Derivatives not designated as hedging instruments:
Commodity derivatives(1)
Other current assets$509.2 $(479.3)$48.9 $(24.8)
Commodity derivatives(1)
Other current liabilities959.9 (970.5)930.7 (943.8)
Commodity derivatives(1)
Other long-term assets2.3 (2.2)2.4 (2.3)
Commodity derivatives(1)
Other long-term liabilities654.4 (654.6)415.2 (415.8)
RIN commitment contracts(2)
Other current assets122.5 0 33.6 0 
RIN commitment contracts(2)
Other current liabilities0 (11.6)0 (22.5)
Derivatives designated as hedging instruments:
Commodity derivatives (1)
Other current assets0 0 0.5 (0.3)
Total gross fair value of derivatives$2,248.3 $(2,118.2)$1,431.3 $(1,409.5)
Less: Counterparty netting and cash collateral(3)
2,097.7 (2,095.9)1,358.3 (1,373.1)
Total net fair value of derivatives$150.6 $(22.3)$73.0 $(36.4)
(1)As of March 31, 2021 and December 31, 2020, we had open derivative positions representing 160,365,527 and 159,682,606 barrels, respectively, of crude oil and refined petroleum products. There were 0 open positions designated as cash flow hedging instruments as of March 31, 2021 and December 31, 2020. Additionally, as of December 31, 2020, we had open derivative positions representing and 22,130,000 MMBTU of natural gas products. There were 0 open natural gas positions as of March 31, 2021.
   June 30, 2020 December 31, 2019
Derivative TypeBalance Sheet Location Assets Liabilities Assets Liabilities
Derivatives not designated as hedging instruments:        
Commodity derivatives(1)
Other current assets $1,364.3
 $(1,316.4) $188.9
 $(202.1)
Commodity derivatives(1)
Other current liabilities 407.3
 (426.8) 24.4
 (34.0)
Commodity derivatives(1)
Other long-term liabilities 366.3
 (369.1) 23.4
 (24.8)
RIN commitment contracts(2)
Other current assets 4.1
 —
 0.6
 —
RIN commitment contracts(2)
Other current liabilities —
 (4.3) —
 (1.9)
          
Derivatives designated as hedging instruments:        
Commodity derivatives (1)
Other current assets 4.5
 (2.7) 3.4
 (2.0)
Commodity derivatives (1)
Other long-term assets —
 —
 0.2
 (0.1)
Total gross fair value of derivatives $2,146.5
 $(2,119.3) $240.9
 $(264.9)
Less: Counterparty netting and cash collateral(3)
 2,081.2
 (2,092.8) 210.7
 (249.5)
Total net fair value of derivatives $65.3
 $(26.5) $30.2
 $(15.4)
(2)As of March 31, 2021 and December 31, 2020, we had open RINs commitment contracts representing 281,608,496 and 282,150,000 RINs, respectively.
(3)As of March 31, 2021 and December 31, 2020, $(1.8) million and $14.8 million, respectively, of cash (obligation) collateral held by counterparties has been netted with the derivatives with each counterparty.
(1)
As of June 30, 2020 and December 31, 2019, we had open derivative positions representing 289,196,954 and 86,484,065 barrels, respectively, of crude oil and refined petroleum products. Of these open positions, contracts representing 180,000 and 600,000 barrels were designated as cash flow hedging instruments as of June 30, 2020 and December 31, 2019, respectively. Additionally, as of June 30, 2020 and December 31, 2019, we had open derivative positions representing 50,830,000 and 40,050,000 One Million British Thermal Units, ("MMBTU") of natural gas products, respectively.
(2)
As of June 30, 2020 and December 31, 2019, we had open RIN commitment contracts representing 103,400,000 and 147,000,000 RINs, respectively.
(3)
As of June 30, 2020 and December 31, 2019, $11.5 million and $38.8 million, respectively, of cash collateral held by counterparties has been netted with the derivatives with each counterparty.
Total gains (losses) on our hedging derivatives and RINRINs commitment contracts recorded in the condensed consolidated statements of income are as follows (in millions):
Three Months Ended March 31,
20212020
Gains on derivatives not designated as hedging instruments recognized in cost of materials and other (1)
$57.2 $77.2 
Losses on commodity derivatives not designated as hedging instruments recognized in other operating income, net (1) (2)
(1.1)0 
Realized gains reclassified out of accumulated other comprehensive income and into cost of materials and other on commodity derivatives designated as cash flow hedging instruments0.2 0.7 
 Total gains$56.3 $77.9 
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
(Losses) gains on commodity derivatives not designated as hedging instruments recognized in cost of materials and other (1)
 $(156.6) $45.5
 $(91.0) $84.4
(Losses) gains on commodity derivatives not designated as hedging instruments recognized in other operating income, net (1) (2)
 (3.7) 2.8
 7.9
 0.5
Realized losses (gains) reclassified out of accumulated other comprehensive income and into cost of materials and other on commodity derivatives designated as cash flow hedging instruments 2.2
 (14.8) 2.9
 (33.9)
 Total (losses) gains $(158.1) $33.5
 $(80.2) $51.0

(1)     Gains on commodity derivatives that are economic hedges but not designated as hedging instruments include unrealized gains of $11.2 million and $52.0 million for the three months ended March 31, 2021 and 2020, respectively.
(2)    See separate table below for disclosures about "trading derivatives."
(1)
Gains (losses) on commodity derivatives that are economic hedges but not designated as hedging instruments include unrealized (losses) gains of $(23.4) million and $28.6 million for the three and six months ended June 30, 2020, respectively, and $(3.6) million and $(30.7) million for the three and sixmonths endedJune 30, 2019, respectively. Of these amounts, approximately $33.4 million and$(0.8) millionas of June 30, 2020 and June 30, 2019, respectively, represent unrealized gains (losses) where the instrument has matured but where it has not cash settled as of period end. Derivative instruments that have matured but not cash settled at the balance sheet date continue to be reflected in derivative assets or liabilities on our balance sheet.
(2)
See separate table below for disclosures about "trading derivatives."

The effect of cash flow hedge accounting on the condensed consolidated statements of income is as follows (in millions):
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Gain (loss) on cash flow hedging relationships recognized in cost of materials and other:        
Commodity contracts:        
Hedged items $(2.2) $14.8
 $(2.9) $33.9
Derivative designated as hedging instruments 2.2
 (14.8) 2.9
 (33.9)
Total $—
 $—
 $—
 $—

Three Months Ended March 31,
20212020
Gain (loss) on cash flow hedging relationships recognized in cost of materials and other:
Commodity contracts:
Hedged items$(0.2)$(0.7)
Derivative designated as hedging instruments0.2 0.7 
Total$0 $0 
28
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Notes to Condensed Consolidated Financial Statements (Unaudited)

For cash flow hedges, 0 component of the derivative instruments’ gains or losses was excluded from the assessment of hedge effectiveness for the three and six months ended June 30, 2020March 31, 2021 or 2019.2020. Gains, (losses), net of tax, on settled commodity contracts of $1.7$0.2 million and $2.3$0.6 million during the three and six months ended June 30,March 31, 2021 and 2020, respectively, and $(11.7) million and $(26.8) million during the three and six months ended June 30, 2019, respectively, were reclassified into cost of materials and other in the condensed consolidated statements of income. As of June 30, 2020,March 31, 2021, we estimate that $1.9 million0 amount of deferred gains related to commodity cash flow hedges will be reclassified into cost of materials and other over the next 12 months as a result of hedged transactions that are forecasted to occur.
Total (losses) gainslosses on our trading physical forward contract derivatives (none of which were designated as hedging instruments) recorded in other operating income, (expense), net on the condensed consolidated statements of income are as follows (in millions):
Three Months Ended March 31,
20212020
Realized losses$(0.4)$(1.7)
Unrealized losses(0.4)(1.0)
 Total$(0.8)$(2.7)
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Realized (losses) gains $(1.2) $0.8
 $(2.9) $4.7
Unrealized (losses) gains 0.3
 —
 (0.7) 2.1
 Total $(0.9) $0.8
 $(3.6) $6.8


Note 10 - Fair Value Measurements
Our assets and liabilities that are measured at fair value include commodity derivatives, investment commodities, environmental credits obligations and Supply and Offtake Agreements. Delek applies the provisions of ASC 820, Fair Value Measurements ("ASC 820"), which defines fair value, establishes a framework for its measurement and expands disclosures about fair value measurements. ASC 820 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 as normal purchases or normal sales 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.
Investment commodities, which represent those commodities (generally crude oil) physically on hand as a result of trading activities with physical forward contracts, are valued using published market prices of the commodity on the applicable exchange and are, therefore, classified as Level 1. Such investment stores, included in other current assets on the condensed consolidated balance sheets, are maintained on a weighted average cost basis for determining realized gains and losses on physical sales under forward contracts, and ending balances are adjusted to fair value at each reporting date. The unrealized gain (loss) on commodity investments for the three and six months ended June 30, 2020 totaled $8.9 million and $1.0 million, respectively, and totaled $(1.0) million and $(2.0) million for the three and six months ended June 30, 2019, respectively.
In April 2020, we entered into a contract with the Department of Energy to deposit one million barrels of crude oil into one of the Strategic Petroleum Reserve ("SPR") storage locations where they will be stored on our behalf until October 2020 for a fee of approximately 100,000 barrels. The fee of 100,000 barrels was recorded as a prepaid asset at cost, and the right to receive the 900,000 barrels was recorded as a financial asset (the "Right to receive crude oil barrels"), measured at fair value based on the value of the underlying commodity using published market prices of the commodity on the applicable exchange. Such asset is, therefore, classified as Level 2. The unrealized gain on the underlying commodity related to the SPR financial asset for the three and six months ended June 30, 2020 of $9.7 million was recorded in other (income) expense, net.
Our RINRINs 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.Obligation (as defined in the Annual Report on Form 10-K). These RINRINs commitment contracts (which are forward contracts accounted for as derivatives – see Note 9) 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 is based onincludes the amount ofConsolidated Net RINs Obligation surplus or deficit, as well as other emissions creditsenvironmental credit obligation surplus or deficit positions subject to fair value accounting that we must purchase, net of amounts internally generated and purchased and the price of those RINs or other emissions credits as of the balance sheet date, by refinery/obligor.pursuant to our accounting policy (see Note 14). 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.

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Notes to Condensed Consolidated Financial Statements (Unaudited)

The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of Delek's assets and liabilities that fall under the scope of ASC 825. As of and for the sixthree months ended June 30,March 31, 2021 and 2020, and 2019, we elected to account for our J. Aron step-out liability at fair value in accordance with ASC 825, as it pertains to the fair value option. This standard permits the election to carry financial instruments and certain other items similar to financial instruments at fair value on the balance sheet, with all changes in fair value reported in earnings. With respect to the amended and restated Supply and Offtake Agreements, such amendments being effective April 2020 for all the 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 Supply and Offtake Agreements 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 condensed consolidated statements of income. Before the January 2020 amendments, we determined
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Notes to Condensed Consolidated Financial Statements (Unaudited)
For all other financial instruments, the fair value forapproximates the fixed price step-out liability based on changes to interest rates reflecting changes tohistorical or amortized cost basis comprising our carrying value and therefore are not included in the interest rate risk, with obligation categorized as Level 2.
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):
 March 31, 2021
 Level 1Level 2Level 3Total
Assets    
Commodity derivatives$0 $2,125.8 $0 $2,125.8 
RINs commitment contracts0 122.5 0 122.5 
Total assets0 2,248.3 0 2,248.3 
Liabilities 
Commodity derivatives0 (2,106.6)0 (2,106.6)
RINs commitment contracts0 (11.6)0 (11.6)
Environmental credits obligation deficit0 (220.8)0 (220.8)
J. Aron supply and offtake obligations0 (410.7)0 (410.7)
Total liabilities0 (2,749.7)0 (2,749.7)
Net assets (liabilities)$0 $(501.4)$0 $(501.4)
  June 30, 2020
  Level 1 Level 2 Level 3 Total
Assets        
Commodity derivatives $—
 $2,142.4
 $—
 $2,142.4
Commodity investments 1.0
 —
 —
 1.0
Right to receive crude oil barrels —
 35.7
 —
 35.7
RIN commitment contracts —
 4.1
 —
 4.1
Total assets 1.0
 2,182.2
 —
 2,183.2
Liabilities        
Commodity derivatives —
 (2,115.0) —
 (2,115.0)
RIN commitment contracts —
 (4.3) —
 (4.3)
Environmental credits obligation deficit —
 (56.6) —
 (56.6)
J. Aron supply and offtake obligations —
 (314.0) —
 (314.0)
Total liabilities —
 (2,489.9) —
 (2,489.9)
Net assets (liabilities) $1.0
 $(307.7) $—
 $(306.7)
  December 31, 2019
  Level 1 Level 2 Level 3 Total
Assets        
Commodity derivatives $—
 $240.3
 $—
 $240.3
Investment commodities 12.1
 —
 —
 12.1
RIN commitment contracts —
 0.6
 —
 0.6
Environmental credits obligation surplus —
 16.8
 —
 16.8
Total assets 12.1
 257.7
 —
 269.8
Liabilities        
Commodity derivatives
—

(263.0)
—

(263.0)
RIN commitment contracts —
 (1.9) —
 (1.9)
Environmental credits obligation deficit —
 (18.5) —
 (18.5)
J. Aron supply and offtake obligations —
 (477.3) —
 (477.3)
Total liabilities —
 (760.7) —
 (760.7)
Net assets (liabilities) $12.1
 $(503.0) $—
 $(490.9)


 December 31, 2020
 Level 1Level 2Level 3Total
Assets    
Commodity derivatives$0 $1,397.7 $0 $1,397.7 
RINs commitment contracts0 33.6 0 33.6 
Total assets0 1,431.3 0 1,431.3 
Liabilities    
Commodity derivatives0 (1,387.0)0 (1,387.0)
RINs commitment contracts0 (22.5)0 (22.5)
Environmental credits obligation deficit0 (59.6)0 (59.6)
J. Aron supply and offtake obligations0 (354.1)0 (354.1)
Total liabilities0 (1,823.2)0 (1,823.2)
Net assets (liabilities)$0 $(391.9)$0 $(391.9)
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Notes to Condensed Consolidated Financial Statements (Unaudited)

The derivative values above are based on analysis of each contract as the fundamental unit of account as required by ASC 820. In the table above, derivative assets and liabilities with the same counterparty are not netted where the legal right of offset exists. This differs from the presentation in the financial statements which reflects our policy, wherein we have elected to offset the fair value amounts recognized for multiple derivative instruments executed with the same counterparty and where the legal right of offset exists. As of June 30, 2020March 31, 2021 and December 31, 2019, $11.52020, $(1.8) million and $38.8$14.8 million, respectively, of cash (obligation) collateral was held by counterparty brokerage firms and has been netted in the financial statements with the net derivative positions with each counterparty. See Note 9 for further information regarding derivative instruments.

Note 11 - 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.
On April 8, 2021, an action titled CVR Energy Inc. v. Delek US Holdings, Inc., Case No. 2021-0297-JTL, was filed in the Court of Chancery of the State of Delaware. The complaint asserts claims arising out of the Company's response to the plaintiff's demand to inspect certain books and records of the Company purportedly pursuant to Section 220 of the Delaware General Corporation Law. The complaint seeks
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Notes to Condensed Consolidated Financial Statements (Unaudited)
an order from the court compelling the Company to provide certain books and records to the plaintiff for purposes of inspection and copying.
One of our Alon subsidiaries was the defendant in a legal action related to an easement dispute arising from a purchase of property that occurred in October 2013. In June 2019, the court found in favor of the plaintiffs and assessed damages against such subsidiary, totaling $6.7 million, which were reduced in the fourth quarter of 2019 to $6.4 million. Such amount is included as of June 30,March 31, 2021 and December 31, 2020 in accrued expenses and other current liabilities on the accompanying condensed consolidated balance sheet.
Self-insurance
Delek records a self-insurance accrual forWith respect to workers’ compensation claims, we are subject to claims losses up to a $4.0 million deductible on a per accident basis, general liability claims up to $4.0 million on a per occurrence basis and medical claims for eligible full-time employees up to $0.3 million per covered individual per calendar year. We are also record a self-insurance accrual forsubject to auto liability claims losses up to a $4.0 million deductible on a per accident basis.
We have umbrella liability insurance available to each of our segments in an amount determined reasonable by management.
Environmental, Health and Safety
We are subject to extensive federal, state and local environmental and safety laws and regulations enforced by various agencies, including the EPA, the United States Department of Transportation, the Occupational Safety and Health Administration, as well as numerous state, regional and local environmental, safety and pipeline agencies. These laws and regulations govern the discharge of materials into the environment, waste management practices, pollution prevention measures and the composition of the fuels we produce, as well as the safe operation of our plants and pipelines and the safety of our workers and the public. Numerous permits or other authorizations are required under these laws and regulations for the operation of our refineries, renewable fuels facilities, terminals, pipelines, underground storage tanks, trucks, rail cars and related operations, and may be subject to revocation, modification and renewal.
These laws and permits raise potential exposure to future claims and lawsuits involving environmental and safety matters which could include soil and water contamination, air pollution, personal injury and property damage allegedly caused by substances which we manufactured, handled, used, released or disposed of, transported, or that relate to pre-existing conditions for which we have assumed responsibility. We believe that our current operations are in substantial compliance with existing environmental and safety requirements. However, there have been and will continue to be ongoing discussions about environmental and safety matters between us and federal and state authorities, including notices of violations, citations and other enforcement actions, some of which have resulted or may result in changes to operating procedures and in capital expenditures. While it is often difficult to quantify future environmental or safety related expenditures, we anticipate that continuing capital investments and changes in operating procedures will be required for the foreseeable future to comply with existing and new requirements, as well as evolving interpretations and more strict enforcement of existing laws and regulations.
As of June 30, 2020,March 31, 2021, we have recorded an environmental liability of approximately $112.9$112.1 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 $6.6$5.1 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.

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 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 could 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. Based on management’s current review, we have determined that there will likely be adjustments in future periods to current 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. The total amount of exposure is not yet determinable, but based on management’s analysis of potential exposure, it is not expected to be material in relation to our total RINs Obligation.
El Dorado Refinery Fire
On February 27, 2021, our El Dorado refinery experienced a fire in its Penex unit. Six employees were injured in the fire, which is currently being investigated by the Occupational Safety and Health Administration. The facility was in the process of undergoing turnaround activity, so there were no operational disruptions as a result of the fire. During the three months ended March 31, 2021, we incurred workers'
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Notes to Condensed Consolidated Financial Statements (Unaudited)

compensation losses of $3.8 million associated with the fire, which is included in operating expenses in the accompanying condensed consolidated statements of income. Additionally, we recognized accelerated depreciation of $1.0 million in the three months ended March 31, 2021 due to property damaged in the fire. Work to determine the full extent of losses and potential insurance claims continues and will continue until all the affected equipment and processes are brought back online and final testing can be completed. The extent of any incremental losses is not yet determinable and may be subject to insurance recoveries.
Delek maintains property damage insurance policies which have an associated deductible of $5.0 million for the El Dorado refinery. Covered losses in excess of the $5.0 million deductible will be recoverable under the property insurance policies.
Crude Oil and Other Releases
We have experienced several crude oil and other releases involving our assets. There were 0 material releases that occurred during the sixthree months ended June 30, 2020, and 5March 31, 2021. For releases that occurred throughoutin prior years, we have received regulatory closure or a majority of the year 2019. Cleanup operations and site maintenancecleanup and remediation efforts on these and other releases are at various stages of completion. The majority of the remediation efforts for these releases are substantially complete or have received regulatory closure. With the exception of the Sulphur Springs release defined below, we expect regulatory closure in 2020 forcomplete. For the release sites that have not yet received it.
On October 3, 2019, a finished product release involving one of our pipelines occurred near Sulphur Springs, Texas (the "Sulphur Springs Release"). Cleanup operations and site maintenance and remediation on this release have been substantially completed where such costs incurred totaled $7.1 million during 2019. During the three and six months ended June 30, 2020,regulatory closure, we incurred approximately $0.1 million and $0.3 million of additional costs related to final clean-up of this release, respectively. The release is currently in boom maintenance. Ground water monitoring wells were installed in the second quarter of 2020. We expect to conduct quarterly ground water monitoring for at least a year. Additionally, we willreceive regulatory closure in 2021 and do not anticipate material costs associated with any fines or penalties or to complete activities that may be conducting creek bed sediment sampling in the third quarter of 2020. We have filed suit in January 2020 against a third party contractor, seeking damages relatedneeded to this release. We have not received notification that any legal action with respect to fines and penalties will be pursued by theachieve regulatory agencies.closure.
Expenses incurred for the remediation of these crude oil and other releases are included in operating expenses in our condensed consolidated statements of income.
Letters of Credit
As of June 30, 2020,March 31, 2021, we had in place letters of credit totaling approximately $204.6$314.6 million with various financial institutions securing obligations primarily with respect to our commodity transactions for the refining segment and certain of our insurance programs. There were 0 amounts drawn by beneficiaries of these letters of credit at June 30, 2020.March 31, 2021.

Note 12 - Income Taxes
Under ASC 740Income Taxes (“ASC 740”) we used an estimated annual tax rate to record income taxes for the three and six months ended June 30, 2020March 31, 2021 and June 30, 2019.March 31, 2020. Our effective tax rate was (57.3)%12.0% and 36.3%21.3% for the three and six months ended June 30,March 31, 2021 and 2020, respectively, compared to 22.5% and 22.8% for the three and six ended June 30, 2019, 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 months ended June 30, 2020March 31, 2021 as compared to the three and six months ended June 30, 2019March 31, 2020 was primarily due to tax benefit for federal tax credits attributable to the Company’s biodiesel blending operations that were re-enacted in December 2019,first quarter 2020 reversal of a valuation allowance for deferred tax assets in partnership investments due to changes in the future realizability of deferred tax basis differences, and expected net operating loss carryback provided under the CARES Act which allows the Company to recover federal taxes paidchange in prior years at a 35% tax rate creating a 14% tax rate benefit.
On March 27, 2020, the Coronavirus Aid Relief, and Economic Security Act (the "CARES Act") was enacted into law.  The Act includes several significant provisions for corporations, including the usage of net operating losses, interest deductions and payroll benefits.  The Company recognized $16.8 million of current federalstate income tax benefitfootprint for the threeseparate state jurisdictions and six months ended June 30, 2020, attributable to anticipated tax refunds from net operating loss carryback to prior 35% tax rate years under the CARES Act. Additionally, we recorded anchanges in certain state income tax receivable totaling $193 million as of June 30, 2020 related to the net operating loss carryback, which we expect to collect in the first half of 2021.apportionment rates.

Note 13 - Related Party Transactions
Our related party transactions consist primarily of transactions with our equity method investees (See Note 5 ).5). Transactions with our related parties were as follows for the periods presented:
Three Months Ended March 31,
(in millions)20212020
Revenues (1)
$10.4 $7.7 
Cost of materials and other (2)
$15.1 $9.1 
  Three Months Ended June 30, Six Months Ended June 30,
(in millions) 2020 2019 2020 2019
Revenues (1)
 $22.2
 $21.2
 $29.9
 $28.2
Cost of materials and other (2)
 $11.4
 $7.2
 $20.5
 $13.2
(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.
(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.


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Notes to Condensed Consolidated Financial Statements (Unaudited)

Note 14 - Other Current Assets and Liabilities
The detail of other current assets is as follows (in millions):
Other Current AssetsJune 30, 2020 December 31, 2019
Income and other tax receivables$198.5
 $61.9
Short-term derivative assets (see Note 9)65.2
 30.2
RINs assets54.5
 14.5
Right to receive crude oil barrels (see Note 10)35.7
 —
Prepaid expenses20.1
 21.9
Environmental Credits Obligation surplus (see Note 10)6.8
 16.8
Biodiesel tax credit (see Note 2)1.5
 97.5
Investment commodities1.0
 12.1
Other6.7
 13.8
Total$390.0
 $268.7

Other Current AssetsMarch 31, 2021December 31, 2020
Income and other tax receivables$158.7 $142.0 
Short-term derivative assets (see Note 9)150.6 72.9 
Prepaid expenses29.4 21.8 
Other19.5 19.7 
Total$358.2 $256.4 
The detail of other non-current assets is as follows (in millions):
Other Non-Current AssetsJune 30, 2020 December 31, 2019
Supply and Offtake receivable$32.7
 $32.7
Other equity Investments10.4
 8.9
Deferred financing costs7.5
 8.5
Long-term derivative assets (see Note 9)—
 0.1
Other13.8
 17.6
Total$64.4
 $67.8


The detail of accrued expenses and other current liabilities is as follows (in millions):
Accrued Expenses and Other Current LiabilitiesJune 30, 2020 December 31, 2019
Income and other taxes payable90.8
 119.6
Product financing agreements83.1
 21.1
Crude purchase liabilities70.0
 72.1
Environmental Credits Obligation deficit (see Note 10)68.6
 18.5
Short-term derivative liabilities (see Note 9)23.7
 14.1
Employee costs22.0
 47.6
Environmental liabilities (see Note 11)6.6
 8.2
Interest payable5.2
 8.8
Tank inspection liabilities5.1
 5.6
Accrued utilities4.1
 4.4
Other30.1
 26.8
Total$409.3
 $346.8


Accrued Expenses and Other Current LiabilitiesMarch 31, 2021December 31, 2020
Product financing agreements$277.8 $198.0 
Consolidated Net RINs Obligation deficit (see Note 10)220.8 59.6 
Crude purchase liabilities205.6 62.1 
Income and other taxes payable101.7 109.5 
Deferred revenue48.1 16.5 
Employee costs34.6 30.2 
Short-term derivative liabilities (see Note 9)22.2 35.8 
Other51.0 34.7 
Total$961.8 $546.4 
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Notes to Condensed Consolidated Financial Statements (Unaudited)

The detail of other non-current liabilities is as follows (in millions):
Other Non-Current LiabilitiesJune 30, 2020 December 31, 2019
Liability for unrecognized tax benefits$12.9
 $12.1
Tank inspection liabilities9.9
 9.9
Pension and other postemployment benefit liabilities, net3.8
 5.3
Long-term derivative liabilities (see Note 9)2.8
 1.4
Other4.4
 2.2
Total$33.8
 $30.9



Note 15 - 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 5, 2020, 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 Stockcommon stock available for issuance under this plan by 2,120,000 shares to 11,020,000 shares.
Compensation expense related to equity-based awards granted under the Incentive Plans amounted to $5.0$4.5 million and $10.9$5.8 million for the three and six months ended June 30,March 31, 2021 and 2020, respectively, and $6.6 million and $11.4 million for the three and six months ended June 30, 2019, respectively. These amounts are included in general and administrative expenses in the accompanying condensed consolidated statements of income.
As of June 30, 2020,March 31, 2021, there was $48.2$37.3 million of total unrecognized compensation cost related to non-vested share-based compensation arrangements, which is expected to be recognized over a weighted-average period of 2.11.6 years.
We issued net shares of common stock of 143,04493,856 and 246,463102,895 as a result of exercised or vested equity-based awards during the three and six months ended June 30,March 31, 2021 and 2020, respectively, and 139,057 and 383,623 for the three and six months ended June 30, 2019, respectively. These amounts are net of 68,94458,851 and 130,44961,505 shares withheld to satisfy employee tax obligations related to the exercises and vestingsvesting during the three and six months ended June 30,March 31, 2021 and 2020, respectively, and 153,940 and 324,076 for the three and six months ended June 30, 2019, respectively.
Delek Logistics GP, LLC 2012 Long-Term Incentive Plan
The Delek Logistics GP, LLC 2012 Long-Term Incentive Plan (the "LTIP") was adopted by the Delek Logistics GP, LLC board of directors in connection with the completion of Delek Logistics' initial public offering in November 2012. The LTIP is administered by the Conflicts Committee of the board of directors of Delek Logistics' general partner.

Note 16 - Shareholders' Equity
Dividends Suspension
DuringWe have elected to suspend dividends beginning in the six months ended June 30,fourth quarter of 2020 our Board of Directors declared the following dividends:in order to conserve capital.
Approval Date30 |Dividend Amount Per ShareRecord DatePayment Date
February 24, 2020$0.31March 10, 2020March 24, 2020
May 4, 2020$0.31May 20, 2020June 3, 2020
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Notes to Condensed Consolidated Financial Statements (Unaudited)
Stock Repurchase Program
On November 6, 2018, our Board of Directors authorized a share repurchase program for up to $500.0 million of Delek common stock. Any share repurchases under the repurchase program may be implemented through open market transactions or in privately negotiated transactions, in accordance with applicable securities laws. The timing, price and size of repurchases are made at the discretion of management and will depend on prevailing market prices, general economic and market conditions and other considerations. The repurchase program does not obligate us to acquire any particular amount of stock and does not expire. During the sixthree months ended June 30,March 31, 2020, 58,713 shares of our common stock were repurchased for a total of $1.9 million. NaNNo repurchases of our common stock were made in the three months

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Notes to Condensed Consolidated Financial Statements (Unaudited)

ended June 30, 2020. During the three and six months ended June 30, 2019, we repurchased 1,647,078 and 2,938,722 shares of our common stock for a total of $58.6 million and $104.8 million, respectively.March 31, 2021. As of June 30, 2020,March 31, 2021, there was $229.7 million of authorization remaining under Delek's aggregate stock repurchase program. In the second quarter of 2020, we elected to suspend the share repurchase program.
Stockholder Rights Plan
On March 20, 2020, our Board of Directors declared a dividend of one preferred share purchase right (a “Right”) for each outstanding share of Delek’s common stock and adopted a stockholder rights plan (the “Rights Agreement”). The dividend was distributed in a non-cash transaction on March 30, 2020 to the stockholders of record on that date. The Rights initially tradetraded with and are inseparable from, Delek’s common stock. Once the Rights become exercisable, each Right will allow its holder to purchase one one-thousandth of a share of Series A Junior Participating Preferred Stock, par value $0.01 per share (a “Preferred Share”) for $92.24, subject to adjustment (the “Exercise Price”). This portion of a Preferred Share will give the stockholder approximately the same dividend, voting and liquidation rights as would one share of Delek’s common stock. Prior to exercise, the Right does not give its holder any dividend, voting or liquidation rights.
The Rights will not be exercisable until 10 days afterexpired in accordance with the public announcement that a person or group that has become an “Acquiring Person” (as defined in the Rights Agreement). The point at which these terms are met is otherwise referred to as the "Distribution Date." If a person or group becomes an Acquiring Person, all holders of Rights except the Acquiring Person may, for the Exercise Price, purchase shares of the Company’s common stock with a market value of two times the Exercise Price, based on the market price of the common stock prior to such acquisition. In addition, subject to certain conditions set forth in the Rights Agreement the Board may extinguish the Rights. If the Company is later acquired in a merger or similar transaction after the Distribution Date, all holders of Rights except the Acquiring Person may, for the Exercise Price, purchase shares of the acquiring corporation with a market value of two times the Exercise Price, based on the market price of the acquiring corporation’s stock prior to such merger.
In the event the Company receives a fully financed, all-cash tender offer satisfying the conditions set forth in the Rights Agreement (a “Qualifying Offer”), and certain other events occur, the Rights Agreement provides a mechanism for stockholders holding more than 20% of the shares of Delek common stock then outstanding (excluding shares beneficially owned by the person making the Qualifying Offer) to demand a special meeting of the stockholders of the Company to vote on a resolution exempting such Qualifying Offer from the provisions of the Rights Agreement.
The Rights will expire on March 19, 2021, subject to a possible earlier expiration to the extent provided in the Rights Agreement.
Preferred Stock
On March 20, 2020, our Board of Directors authorized 1,000,000 shares of preferred stock with a par value of $0.01 per share as Series A Junior Participating Preferred Stock.

2021.

Note 17 - Employees
Postretirement Benefits
The net periodic (benefit) cost for our postretirement benefit plans was not material for the three and six months ended June 30, 2020 or 2019. Additionally, our estimated contributions to our pension plans during 2020 have not changed significantly from amounts previously disclosed in the notes to the consolidated financial statements for the year ended December 31, 2019.

Leases
Note 18 - Leases
We lease certain retail stores, land, building and various equipment from others. Leases with an initial term of 12 months or less are not recorded on the balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term. Most leases include one or more options to renew, with renewal terms that can extend the lease term from one to 15 years or more. The exercise of existing lease renewal options is at our sole discretion. Certain leases also include options to purchase the leased property. The depreciable life of assets and leasehold improvements are limited by the expected lease term, unless there is a transfer of title or purchase option reasonably certain of exercise.
Some of our lease agreements include a rate based on equipment usage and others include a rate with fixed increases or inflationary indices based increase. Our lease agreements do not contain any material residual value guarantees or material restrictive covenants. We rent or sublease certain real estate and equipment to third parties. Our sublease portfolio consists primarily of operating leases within our retail stores and crude storage equipment.
As of June 30, 2020, $27.3March 31, 2021, $26.0 million of our net property, plant, and equipment balance is subject to an operating lease. This agreement does not include options for the lessee to purchase our leasing equipment, nor does it include any material residual value guarantees or material restrictive covenants. The agreement includes a one year-year renewal option and certain variable payment based on usage.

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Notes to Condensed Consolidated Financial Statements (Unaudited)

The following table presents additional information related to our operating leases in accordance ASC 842, Leases ("ASC 842"):
 Three Months Ended June 30, Six Months Ended June 30,Three Months Ended March 31,
(in millions) 2020 2019 2020 2019(in millions)20212020
Lease Cost        Lease Cost
Operating lease costs $15.9
 $17.1
 $31.6
 $30.6
Short-term lease costs (1)
 6.1
 3.7
 13.7
 7.3
Operating lease costs (1)
Operating lease costs (1)
$17.7 $15.7 
Short-term lease costs (2)
Short-term lease costs (2)
9.5 7.6 
Sublease income (2.0) (2.8) (3.9) (4.5)Sublease income(1.9)(1.9)
Net lease costs $20.0
 $18.0
 $41.4
 $33.4
Net lease costs$25.3 $21.4 
        
Other Information        Other Information
Cash paid for amounts included in the measurement of lease liabilities:        Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases $(15.9) $(17.1) $(31.6) $(30.6)
Operating cash flows from operating leases (1)
Operating cash flows from operating leases (1)
$(18.3)$(15.7)
Leased assets obtained in exchange for new operating lease liabilities $15.4
 $8.1
 $22.2
 $8.1
Leased assets obtained in exchange for new operating lease liabilities$7.4 $6.8 
        
Leased assets obtained in exchange for new financing lease liabilitiesLeased assets obtained in exchange for new financing lease liabilities$12.2 $— 
     June 30, 2020  March 31, 2021
Weighted-average remaining lease term (years) operating leases     6.4
  Weighted-average remaining lease term (years) operating leases5.1
Weighted-average discount rate operating leases (2)
     6.0%  
Weighted-average remaining lease term (years) financing leasesWeighted-average remaining lease term (years) financing leases7.7
Weighted-average discount rate operating leases (3)
Weighted-average discount rate operating leases (3)
6.4 %
Weighted-average discount rate financing leases (3)
Weighted-average discount rate financing leases (3)
3.3 %
(1)Includes an immaterial amount of financing lease cost.
(2)Includes an immaterial amount of variable lease cost.
(2) (3) Our discount rate is primarily based on our incremental borrowing rate in accordance with ASC 842.842

.
Note 19 - Subsequent Events
Dividend Declaration
On August 3, 2020, our Board of Directors voted to declare a quarterly cash dividend of $0.31 per share of our common stock, payable on September 3, 2020 to shareholders of record on August 19, 2020.









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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 as filed with the Securities and Exchange Commission ("SEC") on February 28, 2020March 1, 2021 (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 Securities and Exchange Commission,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.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 regarding the effect, impact, potential duration or other implications of, or expectations expressed with respect to, the recent outbreak of COVID-19 and its development into a pandemic in March 2020 (the "COVID-19 Pandemic" or the "Pandemic") and the actions of members of the Organization of Petroleum Exporting Countries (“OPEC”("OPEC") and Russiaother leading oil producing countries (together with OPEC, “OPEC+”), with respect to oil production and pricing, and statements regarding our efforts and plans in response to such events, the information concerning our planned capital expenditures by segment for 2021, possible future results of operations, business and growth strategies, financing plans, expectations that regulatory developments or other matters will or will not have a material adverse effect on our business or financial condition, our competitive position and the effects of competition, the projected growth of the industry in which we operate, and the benefits and synergies to be obtained from our completed and any future acquisitions, statements of management’s goals and objectives, and other similar expressions concerning matters that are not historical facts. Words such as "may," "will," "should," "could," "would," "predicts," "potential," "continue," "expects," "anticipates," "future," "intends," "plans," "believes," "estimates," "appears," "projects" and similar expressions, as well as statements in future tense, identify forward-looking statements.
Forward-looking statements should not be read as a guarantee of future performance or results, and will not necessarily be accurate indications of the times at, or by, which such performance or results will be achieved. Forward-looking information is based on information available at the time and/or management’s good faith belief with respect to future events, and is subject to risks and uncertainties that could cause actual performance or results to differ materially from those expressed in the statements. Important factors that, individually or in the aggregate, could cause such differences include, but are not limited to:
•volatility in our refining margins or fuel gross profit as a result of changes in the prices of crude oil, other feedstocks and refined petroleum products and the impact of the COVID-19 Pandemic on such demand;
•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 the COVID-19 Pandemic;
the possibility of inefficiencies, curtailments, or shutdowns in refinery operations or pipelines, whether due to infection in the workforce or in response to reductions in demand as a result of the COVID-19 Pandemic;
•our ability to execute our strategy of growth through acquisitions and capital projects and changes in the expected
value of and benefits derived therefrom, including any ability to successfully integrate acquisitions, realize expected synergies or achieve operational efficiency and effectiveness;
•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 unprecedented market environment and economic effects of the COVID-19 pandemic,Pandemic, including uncertainty
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Management's Discussion and Analysis

regarding the timing, pace and extent of economic recovery in the United States due to the COVID-19 Pandemic;
•general economic and business conditions affecting the southern, southwestern and western United States, particularly levels of spending related to travel and tourism and the ongoing and future impacts of the COVID-19 Pandemic;
•volatility under our derivative instruments;

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Management's Discussion and Analysis


•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 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 the J. Aron S&Osupply and offtake liability 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;
•the inabilitysuspension of our subsidiaries to freely make dividends, loans or other cash distributions to us;
quarterly dividend;
•seasonality;
seasonality;
•acts of terrorism (including cyber-terrorism) aimed at either our facilities or other facilities that could impair our ability to produce or transport refined products or receive feedstocks;
•future decisions by OPEC+ members regarding production and pricing and disputes between OPEC+ members regarding such;
•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 the headings "Management’s Discussion and Analysis of Financial Condition and Results of Operations" and "Risk Factors" and in our other filings with the SEC.
In light of these risks, uncertainties and assumptions, our actual results of operations and execution of our business strategy could differ materially from those expressed in, or implied by, the forward-looking statements, and you should not place undue reliance upon them. In addition, past financial and/or operating performance is not necessarily a reliable indicator of future performance, and you should not use our historical performance to anticipate future results or period trends. We can give no assurances that any of the events anticipated by any forward-looking statements will occur or, if any of them do, what impact they will have on our results of operations and financial condition.
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.
Executive Summary
Business Overview
We are an integrated downstream energy business focused on petroleum refining, the transportation, storage and wholesale distribution of crude oil, intermediate and refined products and convenience store retailing. Our operating segments consist of refining, logistics, and retail, and are discussed in the sections that follow.
The recentImpact of the COVID-19 Pandemic
The outbreak of COVID-19 and its development into a pandemic in March 2020 (the "COVID-19 Pandemic" or the "Pandemic")Pandemic has resulted in significant economic disruption globally, including in the U.S.United States and specific geographic areas where we operate. Actions taken by various governmental authorities, individuals and companies around the world to prevent the spread of COVID-19 through both voluntary and mandated social distancing, curfews, shutdowns and expanded safety measures have restricted travel, many business operations, public gatherings and the overall level of individual movement and in-person interaction across the globe. This has in turn significantly reduced global economic activity which has had a significant impact on the nature and extent of travel. The COVID-19 Pandemic has had a devastating impact on the airline industry, dramatically reducing the number of domestic flights and, due to foreign travel bans and immigration restrictions abroad as well as traveler concerns over exposure, virtually eliminating international travel originating from the U.SU.S. to many parts of the world. Additionally, the COVID-19 Pandemic has had a significant negative impact on motor vehicle use at a time when seasonal driving patterns typically result in an increase of consumer demand for gasoline.activity. As a result, there has also beenand certainly during 2020, we experienced a decline in the demand for, and thus also the market prices of, crude oil and certain of our products, particularly our refined petroleum products and most notably gasoline and jet fuel. In April and June 2020, agreements were reached to cut oil production between the members of the Organization of Petroleum Exporting Countries ("OPEC") and other leading oil producing countries (together with OPEC, “OPEC+”), as part of the efforts to resolve the oil production disputes that significantly affected crude oil prices beginning in the first quarter of 2020 (the "OPEC Production Disputes"), and to provide stability in the oil markets. While OPEC+ have reached an agreement to cut oil production, the uncertaintyUncertainty about the duration of the COVID-19 Pandemic has caused periodic storage constraints in the United States U.S.
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Management's Discussion and Analysis

resulting from over-supply of produced oil.oil, while some of this oversupply was alleviated during and after Winter Storm Uri, which caused disruption in pipelines and other supply sources in PADD 3 during February and early March. While in the last few months, we have seen successful domestic efforts to distribute the vaccine across the U.S. which has led to some improved stability in the capital markets as well as improved pricing in crude oil, refined products and related forward curves, there continues to be uncertainty, and demand for refined product, and likewise for our logistics assets, has not yet returned to normal levels. Based on these conditions and events, downward pressure on commodity prices, crack spreads and demand remains a significant risk and could continue for the foreseeable future.

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Management's Discussion and Analysis


During the latter part of the second quarter of 2020, governmental authorities in various states across the U.S., particularly those in our Permian Basin and U.S. Gulf Coast regions, began to lift many of the restrictions created by actions taken to slow down the spread of COVID-19. These actions have resulted in an increase in the level of individual movement and travel and, in turn, an increase in the demand and market prices for some of our products relative to late March 2020. However, many of the states where such restrictions were lifted have recently experienced a marked increase in the spread of COVID-19 and many governmental authorities in such areas have responded by reimposing certain restrictions they had previously lifted. This response, as well as the increased infection rates, impacts regions that we serve and could significantly impact demand in ways that we cannot predict. Additionally, increased infection rates could impact our refining, logistics and retail operations, particularly in high-infection states, if our employees are personally affected by the illness, both through direct infection and quarantine procedures.
During the three and six months ended June 30, 2020, Delek has experienced the impact on demand and pricing of these unprecedented conditions, most notably in our refining segment. Our business and our second quarter 2020 results reflect the impact of decreased demand combined with crack spreads that are 62% to 76% lower, on average, compared to the same quarter in the prior year. We have also experienced operational constraints as well, including COVID-19 infections at certain of our company locations that have resulted in re-imposed or expanded remote policies and quarantine protocols. And we continue to be faced with risk from our suppliers and customers who are facing similar challenges.
We havepreviously identified the following known uncertainties resulting from the COVID-19 PandemicPandemic. And while the risk surrounding these uncertainties appears to be lessening, they still represent risks that could impact our operations, financial condition and the OPEC Production Disputes:results of operations. They are as follows:
•Significant declines and/or volatility in prices of refined products we sell and the feedstocks we purchase as well as in crack spreads resulting from the COVID-19 Pandemic and the OPEC Production Disputes could have a significant impact on our revenues, cost of sales, operating income and liquidity, as well to the carrying value of orour long-lived or indefinite-lived assets;
•A decline in the market prices of refined products and feedstocks below the carrying value in our inventory may result in the adjustment of the value of our inventories to the lower market price and a corresponding loss on the value of our inventories (see also Note 1 to our Condensed Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q for additional discussion of specific financial statement risks);
•The decline in demand for refined productproducts could significantly impact the demand for throughput at our refineries, unfavorably impacting operating results at our refineries, and could impact the demand for storage, which could impact our logistics segment;
•The decline in demand and margins impacting current results and forecasts could result in impairments in certain of our long-lived or indefinite-lived assets, including goodwill, or have other financial statement impacts that cannot currently be anticipated (see also Note 1 to our Condensed Consolidated Financial Statements included in Part I, Item 1 of this Quarterly Report on Form 10-Q for additional discussion of specific financial statement risks);
•A significant reduction or suspension in U.S. crude oil production could adversely affect our suppliers and sources of crude oil;
•An outbreak in one of our refineries, exacerbated by a limited pool of qualified replacements as well as quarantine protocols, could cause significant disruption in our production or, worst case, temporary idling of the facility;
•The restrictions on travel and requirements for social distancing could significantly impact the traffic at our convenience stores, particularly the demand for fuel;
•Customers of the refining segment as well as third-party customers of the logistics segment may experience financial difficulties which could interrupt the volumes ordered by those customers and/or could impact the credit worthiness of such customers and the collectability of their outstanding receivables;
•The impact of COVID-19 or protocols implemented in response to COVID-19 by key or specialty suppliers may negatively affect our ability to obtain specialty equipment or services when needed;
•Equity method investees may be significantly impacted by the COVID-19 Pandemic and/or the OPEC Production Disputes, which may increase the risk of impairment of those investments;
•Access to capital markets may be significantly impacted by the volatility and uncertainty in the oil and gas market specifically which could restrict our ability to raise funds;
While while our current liquidity needs are managed by existing facilities, sources of future liquidity needs may be impacted by the volatility in the debt market and the availability and pricing of such funds as a result of the COVID-19 PandemicPandemic; and the OPEC Production Disputes; and
•The U.S. Federal Government has enacted certain stimulus and relief measures including the Coronavirus Aid, Relief, and Economic Security Act (the "CARES Act") passed on March 27, 2020, and is continuing tomay consider additional relief legislation. Beyond the direct impact of existing legislation on Delek in the current period,or prior periods (as applicable), the extent to which the provisions of the existing or any future legislation will achieve its intention to stimulate or provide relief to the greater U.S. economy and/or consumer, as well as the impact and success of such efforts, remains unknown.
Other uncertainties related to the impact of the COVID-19 Pandemic as well as global geopolitical factors may exist that have not been identified or that are not specifically listed above, and could impact our future results of operations and financial position, the nature of which

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Management's Discussion and Analysis


and the extent to which are currently unknown. Actions taken by OPEC+ in April and June 2020, including the agreement for management of crude oil supply in the hopes of contributing to market stabilization (the "Oil Production Cuts"), as well as theThe U.S. Federal Government's passage and/or enactment of additional stimulus and relief measures, as well as their future actions may impact the extent to which the risk underlying these uncertainties are realized. To the extent these uncertainties have been identified and are believed to have an impact on our current period results of operations or financial position based on the requirements for assessing such financial statement impact under U.S. Generally Accepted Accounting Principles ("GAAP"), we have considered them in the preparation of our unaudited financial statements as of and for the sixthree months ended June 30, 2020,March 31, 2021, which are included in Item 1, of this Quarterly Report on Form 10-Q.
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Management's Discussion and Analysis

In addition, management continueshas actively responded to actively respond to the continuing impact of the COVID-19 Pandemic and the OPEC Production Disputes on our business. Additionally, to the extent warranted, we continue to monitor the impact and implement measures to mitigate the risk. Such efforts include (but are not limited to) the following:
•Reviewing planned production throughputs at our refineries and planning for the possibilityoptimization of reductions;operations;
•Coordinating planned maintenance activities with possible downtime as a result of possible reductions in throughputs;
•Searching for additional storage capacity if needed to store potential builds in crude oil or refined product inventories;
•Finding additional suppliers for key or specialty items or securing inventory or priority status with existing vendors;
•Reducing planneddiscretionary capital expenditures for 2020;expenditures;
•Suspending the share repurchase program and dividend distributions until our internal parameters are met for resuming such repurchases;activities;
•Taking advantage of the income and payroll tax relief afforded to us by the CARES Act;Act or other Pandemic relief legislation;
•Implementing regular site cleaning and disinfecting procedures;
•Adopting remote work measuresworking where possible, and where on-site operations are required, taking appropriate safety protocols at our refineries and other locations;precautions;
Reviewing dividend strategy to align with market changes and current economic conditions;
•Identifying alternative financing solutions as needed to enhance our access to sources of liquidity; and
•Enacting cost reduction measures across the organization, including reducing contract services, reducing overtime and other employee related costs, and reducing or eliminating non-critical traveltravel.
The most significant of these efforts to date as well as specifically identified measures that are anticipated in the near term, in terms of realized or anticipated impact, include the following:
•For the year ended December 31, 2020 pursuant to the provisions of the CARES Act, we recognized $16.8 million of current federal income tax benefit attributable to anticipated tax refunds from net operating loss carryback to prior 35% tax rate years, and deferred $10.9 million of payroll tax payments which serveswill be payable in equal installments in December 2021 and December 2022. Additionally, we recorded an income tax receivable totaling $156.2 million as of December 31, 2020 related to the dual purposenet operating loss carryback, which we expect to collect $135.6 million in 2021 and the remaining balance in 2022.
•We made significant efforts to reduce our capital spending, particularly on growth and non-critical sustaining maintenance projects. See the "Liquidity and Capital Resources" section of Item 2. MD&A further information.
•In light of the weak macro-economic environment, we elected to pull forward turnaround work into the fourth quarter of 2020 on certain units at our Krotz Springs refinery that was conducted on a straight-time basis. This allowed us to continue running the more profitable units of the refinery and should help improve economics toward a break-even level. We completed this turnaround work late in the first quarter 2021 and have begun moving back to full utilization at the facility.
•Additionally, we developed a cost savings plan for 2021 designed to continue to reduce operating expenses and general and administrative expenses. The majority of the expected operating expenses reduction is attributable to the temporary unit optimization at the Krotz Springs refinery, while other efforts such as targeted budgeting around outside contractor expenses and deferral of certain non-critical, non-capitalizable maintenance activities are also complying with recommendationsexpected to have a favorable impact. Furthermore, both operating and general and administrative expenses will be favorably impacted by a cumulative reduction in workforce. Reductions in workforce are made possible in large part by significant efforts to improve process efficiency and leverage technology where cost-effective.
•Finally, we elected to suspend dividends beginning in the fourth quarter 2020 in order to conserve capital. We expect this will help us maintain our liquidity and manage our cost of capital impacted by the statePandemic, and federal governments becausewe believe it will provide us with flexibility to pursue opportunities to provide value to investors with respect to our stock price, which we believe is undervalued.
The combination of these efforts are expected to continue to have a favorable impact on cash flows as well as our operations process effectiveness, which will improve our liquidity positioning and operational flexibility and response in anticipation of the continued economic impacts of the COVID-19 Pandemic. See the "Liquidity and Capital Resources" section of Item 2. MD&A for further information.
The extent to which our future results are affected by the COVID-19 Pandemic will depend on various factors and consequences beyond our control, such as the duration and scope of the Pandemic; additional actions by businesses and governments in response to the Pandemic, and the speed and effectiveness of responses to combat the virus.virus and any new variants and the challenges with the vaccination rollout. The COVID-19 Pandemic, and the volatile regional and global economic conditions stemming from the Pandemic, could also exacerbate the risk factors identified in our Annual Report on Form 10-K for the fiscal year ended December 31, 20192020 and in this Form 10-Q.10-Q, as applicable. The COVID-19 Pandemic may also materially adversely affect our results in a manner that is either not currently known or that we do not currently consider to be a significant risk to our business.
See also 'Risk Factors'
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Management's Discussion and Analysis

Other Significant Events
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 Tyler and Big Spring 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. As a result of this event and the related outages at our El Dorado refinery, we accelerated certain of our planned turnaround activities to coincide with repairs of any damaged units, therefore optimizing and limiting our downtime. As a result of the temporary unit optimization at our Krotz Springs refinery, there was limited disruption to its operations. Additionally, the severe weather conditions and the resultant industry downtime caused energy prices to rise in certain regions where we operate, which has resulted in additional operating expenses for the refineries impacted.
On February 27, 2021, our El Dorado refinery experienced a fire in its Penex unit, in which six Delek employees were injured. Our on-site emergency response team, with the assistance of the El Dorado Fire Department, extinguished the fire, and we immediately began to monitor the air quality within the refinery and the community. The incident is currently being investigated by the Occupational Safety and Health Administration. The facility was in the process of undergoing turnaround activity, so there were no operational disruptions as a result of the fire. (See Note 11 to our Condensed Consolidated Financial Statements included in Part II,I, Item 1A.1 of this Quarterly Report on Form 10-Q for further discussion of risks associated with the COVID-19 Pandemicmore information about losses incurred and the OPEC Production Disputes.
Pursuant to the provisions of the CARES Act, we recognized $16.8 million of current federal income tax benefit for the three and six months ended June 30, 2020, attributable to anticipated tax refunds from net operating loss carryback to prior 35% tax rate years. Additionally, we recorded an income tax receivable totaling $193 million as of June 30, 2020 related to the net operating loss carryback, which we expect to collect in the first half of 2021. Finally, we deferred $4.4 million of payroll tax payments under the provisions of the CARES Act during the six months ended June 30, 2020, which will be payable in equal installments in December 2021 and December 2022.

insurance coverages).
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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 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 as of June 30, 2020.March 31, 2021. 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 (barrels per day ("bpd"))75,00080,00073,00074,000
Primary ProductsGasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, petroleum coke and sulfurGasoline, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, asphalt and sulfurGasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, aromatics and sulfurGasoline, jet fuel, high-sulfur diesel, light cycle oil, liquefied petroleum gases, propylene and ammonium thiosulfate
Relevant Crack Spread BenchmarkGulf Coast 5-3-2
Gulf Coast 5-3-2 (1)
Gulf Coast 3-2-1 (2)
Gulf Coast 2-1-1 (3)
Marketing and DistributionThe refining segment's petroleum-based products are marketed primarily in the south central, southwestern and western 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.
 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 (barrels per day ("bpd"))75,000
80,000
73,000
74,000
Primary ProductsGasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, petroleum coke and sulfurGasoline, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, asphalt and sulfurGasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, aromatics and sulfurGasoline, jet fuel, high-sulfur diesel, light cycle oil, liquefied petroleum gases, propylene and ammonium thiosulfate
Relevant Crack Spread Benchmark (1)Gulf Coast 5-3-2Gulf Coast 5-3-2 (2)Gulf Coast 3-2-1 (3)Gulf Coast 2-1-1 (4)
Marketing and DistributionThe refining segment's petroleum-based products are marketed primarily in the south central, southwestern and western 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") 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.
(1)
The term "crack spread" is a measure of the difference between market prices for crude oil and refined products.
(2)
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.
(3)
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") 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.
(4)
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.

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Management's Discussion and Analysis

Logistics Overview
Our logistics segment (or "Logistics") gathers, transports and stores crude oil and markets, distributes, transports and stores refined products in select regions of the southeastern United States and West Texas for our refining segment and third parties. It is comprised of the consolidated balance sheet and results of operations of Delek Logistics Partners, LP ("Delek Logistics", NYSE:DKL), where we owned a 69.1% interest (at June 30, 2020) in Delek Logistics and a 94.8% interest in the entity that owns the entire 2.0% general partneran 80.0% interest in Delek Logistics and all of the incentive distribution rights.at March 31, 2021. 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 pipelines and transportation business owns or leases capacity on approximately 400 miles of crude oil transportation pipelines, approximately 450 miles of refined product pipelines, and an approximately 700-mile900-mile crude oil gathering system and associated crude oil storage tanks with an aggregate of approximately 10.2 million barrels of active shell capacity. Our logistics segmentIt also owns and operates nine light product terminals and markets light products using third-party terminals. The logistics segment alsoLogistics has strategic investments in pipeline joint ventures that provide access to pipeline capacity as well as the potential for earnings from joint venture operations. Additionally, on March 31, 2020, the logistics segment acquired from another of our segments approximately 200 miles of gathering and ancillary assets located in Howard, Borden and Martin Counties, Texas. In May 2020, the logistics segment acquired from another of our segments certain leased and owned tractors and trailers and related assets. The logistics segment owns or leases 273approximately 264 tractors and 324353 trailers used to haul primarily crude oil and other products for related and third parties.


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Management's Discussion and Analysis


Retail Overview
Our retail segment (or "Retail") at June 30, 2020March 31, 2021 includes the operations of 253 owned and leased convenience store sites located primarily in Central and 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. This agreement was amended in April 2020 to extend date forand the requiredterms of such termination and subsequent amendment require the removal of all 7-Eleven branding on a store-by-store basis fromby December 31, 2021 to December 31, 2022. As of June 30, 2020, we have removed the 7-Eleven brand name at 57 of our store locations.2023. Merchandise sales 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 March 31, 2021, we have removed the 7-Eleven brand name at 57 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. In connection with our retailRetail strategic initiatives, as of June 30, 2020, we have closed or sold 46 under-performing or non-strategic store locations since the fourth quarter of which one was closed during the six months ended June 30, 2020.2018.
The cost to acquire the refined fuel products we sell to our wholesale customers in our logistics segment and at our convenience stores in our retail segment depends on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined petroleum products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, production levels, the availability of imports, the marketing of competitive fuels and government regulation. Our retail merchandise sales are driven by convenience, customer service, competitive pricing and branding. Motor fuel margin is sales less the delivered cost of fuel and motor fuel taxes, measured on a cents per gallon basis. Our motor fuel margins are impacted by local supply, demand, weather, competitor pricing and product brand.
Corporate and Other Overview
Our corporate activities, results of certain immaterial operating segments, including our asphalt terminal operations, our recently commenced wholesale crude operations, and intercompany eliminations are reported in corporate, other and eliminations in our segment disclosures. Additionally, our corporate activities include certain of our commodity and other hedging activities.
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Management's Discussion and Analysis

Strategic Overview
The Company's overall strategy has been to take a disciplined approach that looks to balance returning cash to our shareholders and prudently investing in the business to support safe and reliable operations, while exploring opportunities for growth. Our goal has been to balance the different aspects of this program based on evaluations of each opportunity and how it matches our strategic goals for the company,Company, while factoring in market conditions and expected cash generation.flows.
InHaving taken into account the facesignificance of the economic impact of the COVID-19 Pandemic and the OPEC Production Disputes in early 2020, our overall strategy remains unchanged and continues to be focused on the following objectives:
I.     Safety and wellness.
II.    Reliability and integrity.
III.    Systems and processes.
IV.    Risk-based decision making.
V.     Positioning for growth.
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 renewable identification numbers ("RINs") at fixed prices and quantities, which are used to manage the costs of our credits for commitments required by the U.S. Environmental Protection Agency ("EPA") to blend biofuels into fuel products ("RINs Obligation"). Additionally, from a sourcing perspective, we often enter into purchase and sale contracts with vendors and customers or take 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

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Management's Discussion and Analysis


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 net earnings.
With these objectives serving as our guiding principles, we are applying2021 Developments
Our principle focus during the short-term measuresfirst quarter of 2021 was to mitigateexecute on the impactfollowing initiatives, consistent with those discussed above in the context of the COVID-19 Pandemic measures:
•effectively implementing and executing on our operating cost savings initiatives;
•continuing to be focused on controlling capital expenditures;
•focusing on operating efficiently, including the Krotz Springs refinery optimization;
•continuing to position ourselves to manage our supply chain risk, our customer risk and our liquidity sources;
•continuing to maintain a strong retail business; and
•with our sights also set on recovery from the Pandemic and the OPEC Production Disputes described infuture, continuing to explore and investigate growth opportunities for midstream or other lines of business.
While, as previously noted above, COVID-19 conditions seem to be improving, as is the 'Business Overview' above. Andoutlook, with these objectives in mind,the continued successful distribution of effective vaccines, we have achieved the following successes to date in 2020:
2020 Developments
Transactions designed to maximize shareholder return
Dividend Declaration
On August 3, 2020, Delek's Board of Directors voted to declare a quarterly cash dividend of $0.31 per share, payable on September 3, 2020, to stockholders of record on August 19, 2020. Our previous quarterly cash dividend amounts ranged between $0.27 to $0.30 per share for dividends paid throughout 2019 and was $0.31 per share for the dividends paidwere faced with some unprecedented challenges which required our focus during both the first quarter 2021. These included the effects of Winter Storm Uri as well as the El Dorado fire (described above). We believe that managing the efforts listed above, plus managing through the disruption caused by these two unexpected events, were critical to managing our results in this continued challenging environment. That said, and second quarters of 2020.related to the last bullet above, we did successfully execute on a strategic opportunity in our logistics segment, as described below.
Share Repurchases
During the six months ended June 30, 2020, Delek repurchased 58,713 shares for an aggregate purchase price of $1.9 million under the most recent share repurchase plan which provided for repurchases of up to $500.0 million and was approved by the board on November 6, 2018. As of June 30, 2020, there remained $229.7 million available for repurchases under the most recent repurchase plan. In our efforts to conserve capital, for the time being we have suspended the repurchase of shares.
Transactions designed to maximize return on assets
Investment in Midstream VenturesExclusivity Supply Agreement
In July 2019, we acquiredMay 2021, Delek Logistics executed a 15% ownership interest in Wink to Webster Pipelinestrategic exclusivity supply agreement with Baker Petrolite LLC (an affiliate of Baker Hughes Company) ("WWP"Baker"). WWP intends to construct and operate a crude oil pipeline system from Wink, Texas to Webster, Texas along with certain pipelines from Webster, Texas to other destinations in the Gulf Coast area. It is expected to span approximately 650 miles at completion. Under the agreements governing the joint venture, we must contribute our percentage interest of the applicable construction costs (including certain costs previously incurred by WWP), and it is anticipated that our capital contributions will total approximately $340 million to $380 million over the course of construction (expected to be two to three years).
On February 21, 2020, we, through our wholly-owned direct subsidiary Delek Energy, entered into the W2W Holdings LLC ("HoldCo") Agreement with MPLX Operations LLC ("MPLX") (collectively, with its wholly-owned subsidiaries, the "WWP Project Financing Joint Venture" or the "WWP Project Financing JV"). The WWP Project Financing JV was created for the specific purpose of obtaining financing, through its wholly-owned subsidiary, W2W Finance LLC, to fund the majority of our combined capital calls resulting from and occurring during the construction period of the pipeline system under the WWP Joint Venture, and to service that debt. In connection with the arrangement, both Delek Energy and MPLX contributed their respective 15% ownership interests to the WWP Project Financing JV as collateral for and in service of the related project financing. Accordingly, distributions received from WWP through the WWP Project Financing JV will first be applied in service of the related project financing debt, with excess distributions being made to the members of the WWP Project Financing JV as provided for in the W2W Holdings LLC Agreement and as allowed under the project financing debt. The obligations of the members under the W2W Holdings LLC Agreement are guaranteed by the parents of the members of the WWP Project Financing JV (i.e., for the Delek member,supply of chemicals to meet IMO regulations through blending competencies utilizing proprietary intellectual property.The agreement has a 5-year initial term and a 5-year extension option. Terms of the guarantee is from Delek US Holdings, Inc.). Our investment is accounted for as an equity method investment.
See further discussion in Note 5 of our condensed consolidated financial statements included in Item 1, Financial Statements, of this Quarterly Report on Form 10-Q.
Increased Investment inagreement are intended to incentivize a cooperative arrangement relating to strategic blending activities to be operated by Delek Logistics,
Effective May 1, 2020, Delek through its wholly owned subsidiaries Lion Oil Company (“Lion Oil”) and Delek Refining, Ltd. (“Delek Refining”) contributed certain leased and owned tractors and trailers and related assets usedprovides an exciting growth opportunity in the provision of trucking and transportation services for crude oil, petroleum and certain other products throughout Arkansas, Oklahoma and Texas to Delek Trucking, LLC (“Delek Trucking”), a direct wholly owned subsidiary of Lion Oil. Following this contribution, Lion Oil sold all of the issued and outstanding membership interests in Delek Trucking (the “Acquisition”) to DKL Transportation, LLC (“DKL Transportation”), a wholly owned subsidiary of Delek Logistics. Promptly following the consummation of the Acquisition, Delek Trucking merged with and into DKL Transportation, with DKL Transportation continuing as the surviving entity. Total consideration for the Acquisition was approximately $48.0 million in cash, subject to certain post-closing adjustments, primarily financed with borrowings under Delek Logistics’ revolving credit facility.
Effective March 31, 2020, Delek Logistics, through its wholly-owned subsidiary DKL Permian Gathering, LLC, acquired the Big Spring Gathering System, located in Howard, Borden and Martin Counties, Texas, from Delek. Delek Logistics will operate and maintain the Big Spring Gathering System connecting our interests in and to certain crude oil production with the Delek Logistics' Big Spring, Texas terminal and provide gathering, transportation and other related services. The total consideration was subject to certain post-closing adjustments and was comprised of $100.0 million in cash and 5.0 million common units representing limited partner interest in Delek Logistics. The cash component of this dropdown

logistics segment.
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Management's Discussion and Analysis


was financed with borrowings on the Delek Logistics Credit Facility (as defined in Note 8 of our condensed consolidated financial statements included in Item 1, Financial Statements).
Additionally, in March 2020, we purchased 451,822 of Delek Logistics limited partner units from a public investor for approximately $5.0 million. As a result of these transactions, our ownership in Delek Logistics' common limited partner units was increased to 70.5%. These continued investments enhance our ability to maximize the value of our logistics assets.
See further discussion in Note 4 of our condensed consolidated financial statements included in Item 1, Financial Statements, of this Quarterly Report on Form 10-Q.
Sale of Bakersfield Non-Operating Refinery
On May 7, 2020, we sold our equity interests in Alon Bakersfield Property, Inc., an indirect wholly-owned subsidiary that owns our non-operating refinery located in Bakersfield, California, to a subsidiary of Global Clean Energy Holdings, Inc. (“GCE”) for total cash consideration of $40 million. As part of the transaction, GCE granted a call option to Delek to acquire up to a 33 1/3% interest in the acquiring subsidiary, GCE Acquisitions, exercisable by Delek through the 90th day after GCE demonstrates commercial operations, as contractually defined.
See Note 2 of our condensed consolidated financial statements included in Item 1, Financial Statements, of this Quarterly Report on Form 10-Q.
Transactions designed to minimize the cost of capital/manage financial risk exposures
2020 Amendments to Supply and Offtake Agreements
In January 2020, we amended our three Supply and Offtake Agreements with J. Aron which applies to the El Dorado refinery, the Big Spring refinery and the Krotz Springs refinery so that 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") will be based on market-indexed price subject to commodity price risk with corresponding changes to underlying market-based indices and certain differentials. The amendments resulted in Baseline Step-Out Liabilities for which the fair value is no longer subject to interest rate risk but is now subject to commodity price volatility.
In April 2020, we amended and restated our three Supply and Offtake Agreements to amend and extend the terms to December 30, 2022, with J. Aron having the sole discretion to further extend to May 30, 2025 by providing at least six months notice prior to the maturity date. As part of this amendment, there were changes to the underlying market index, annual fee, the crude purchase fee, crude roll fees and timing of cash settlements related to periodic price adjustments on the fixed differential component of the Baseline Volume Step-Out Liabilities. The amendments provide us dedicated financing for the barrels covered through at least December 2022, and certain specific market-indexed provisions improve our ability to manage our exposure to commodity price volatility during the term of the Agreements.
See further discussion in Note 7 of our condensed consolidated financial statements included in Item 1, Financial Statements, of this Quarterly Report on Form 10-Q.
2020 Amendment to the Term Loan Credit Facility
On May 19, 2020, we amended the Term Loan Credit Facility agreement (as defined in Note 8 of our condensed consolidated financial statements included in Item 1, Financial Statements) and borrowed $200.0 million in aggregate principal amount of incremental term loans (the “Third Incremental Term Loan”) at an original issue discount of 7.00%, requiring quarterly principal amortization payments of $0.5 million commencing with June 30, 2020. The Third Incremental Term Loan constitutes a separate class of term loans under the Term Loan Credit Facility from those initially borrowed in March 2018 and the incremental term loans borrowed in May 2019 and November 2019. There are no restrictions on the Company's use of the proceeds of the Third Incremental Term Loan, and the proceeds may be used (i) for general corporate purposes and (ii) to pay transaction fees and expenses associated with the Third Incremental Term Loan.
See further discussion in Note 8 of our condensed consolidated financial statements included in Item 1, Financial Statements, of this Quarterly Report on Form 10-Q.









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Management's Discussion and Analysis


Market Trends
Commodity Prices
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, our profitability has been affected bythe impact of commodity price volatility on our refining margins (as defined in our 'Non-GAAP Measures' on page 45), specifically as it relates to the price of crude oil as compared to the price of refined products and refined products. We have significant sourcestiming 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 RINs.
Crude Prices
WTI Midland crude becauseoil represents the largest component of our crude slate at all of our refineries, and can be sourced through our gathering system, and so accordingly favorable pricing of WTIchannels or optimization efforts from Midland, crude compared to other WTI crude can favorably impact our cost of materials and other and therefore our margins compared to other refiners.
Texas or Cushing, Oklahoma. The table below reflects the quarterly average prices of WTI Midland and WTI Cushing crude oil for each of the quarterly periods in 20192020 and for the twofirst quarterly periodsperiod in 2020.2021. As shown in the historical graph, WTI Midland crude prices can be favorable or unfavorable as compared to WTI Cushing.
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Crude Pricing Differentials
As U.S. crude oil production has increased over recent years, domestic refiners have benefited from the discount for WTI Cushing compared to Brent ("Brent"), a global benchmark crude. This generally been favorableleads 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 differentials of both Brent crude oil and WTI Midland crude oil as compared to WTI Cushing though that trend has reversed slightlycrude oil as well as WTI Cushing as compared to Louisiana Light Sweet crude oil ("LLS") for each of the quarterly periods in 2020 and for the fourth quarter 2019.first quarterly period in 2021.
chart-8b1fc266ebe0514ca59.jpgdk-20210331_g5.jpg
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Management's Discussion and Analysis

Refined Product Prices
Our refineries produce the following products:
Tyler RefineryEl Dorado RefineryBig Spring RefineryKrotz Springs Refinery
Primary ProductsGasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, petroleum coke and sulfurGasoline, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, asphalt and sulfurGasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, aromatics and sulfurGasoline, 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. ULSD for each of the quarterly periods in 2020 and for the first quarterly period in 2021.
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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 and feedstocks/crude oil and the resultant refined products. Generally, a crack spreads representspread 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 Ultra Low Sulfur Diesel ("ULSD"), 3-2-1 and 2-1-1 crack spreads for each of the quarterly periods in 20192020 and for the twofirst quarterly periodsperiod in 2020.2021. As the chart illustrates, the 3-2-1 crack spread has consistently outperformed the 5-3-2 and the 2-1-1 crack spreads. In suchWhen market conditions things being equal (i.e.,consist of near-capacity throughputs and no significant outages),outages, our Big Spring refinery, whose benchmark is the 3-2-1 crack spread, should outperform our other refineries in terms of refining margin.margin, which are benchmarked against either the 5-3-2 or the 2-1-1 crack spreads.
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45

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Management's Discussion and Analysis


Refined Product Prices
Our refineries produce the following products:
Tyler RefineryEl Dorado RefineryBig Spring RefineryKrotz Springs Refinery
Primary ProductsGasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, petroleum coke and sulfurGasoline, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, asphalt and sulfurGasoline, jet fuel, ultra-low-sulfur diesel, liquefied petroleum gases, propylene, aromatics and sulfurGasoline, 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, U.S. High Sulfur Diesel and U.S. Ultra Low Sulfur Diesel for each of the quarterly periods in 2019 and for the two quarterly periods in 2020.
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Crude Pricing Differentials
As U.S. crude oil production has increased over recent years, domestic producers 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, we are even further benefited by discounts in the WTI Midland/WTI Cushing differential. When these discounts shrink or become premiums, our reliance on WTI-linked crude pricing, and specifically WTI Midland crude can negatively impact our results. Conversely, as these price discounts increase, so does our competitive advantage, created by our access to WTI-linked crude oil pricing, and specifically WTI Midland crude sources through our gathering systems.
The chart below illustrates the differentials of both Brent crude oil and WTI Midland crude oil as compared to WTI Cushing crude oil as well as WTI Cushing as compared to Louisiana Light Sweet crude oil ("LLS") for each of the quarterly periods in 2019 and for the two quarterly periods in 2020.
chart-1f5bf6088f6a585fa63.jpg

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Management's Discussion and Analysis


RIN Volatility
Environmentalregulations continue to affect our margins in the form of volatility in the cost ofRINs. On a consolidated basis, we work to balance the cost of our RINs Obligation in order to minimize the effect of RINs on our results. While we generate RINs in both our refining and logistics segments through our ethanol blending and biodiesel production and blending, our refining segment still needs to purchase additional RINs to satisfy its obligations. AsThe cost to purchase these additional RINs is a result,significant cash outflow for our business. Additionally, increases in the pricemarket prices of RINs generally adversely affect our results of operations.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. The volatility of RINs prices is highly sensitive to regulatory and political influence and conditions, and therefore often does not correlate to movements in crude oil prices, refined product prices or crack spreads. Additionally, the pricing of RINs and the resulting impact on a refiner's margins is dependent on the type of refined product produced. Furthermore, RIN prices are impacted by market expectations regarding whether the EPA may grant certain small refinery exemptions. Therefore, the recent judicial rulings overturning certain small refinery exemptions, as well as the new presidential administration's vocal support for faster-moving clean energy initiatives, have caused significant recent increases in RINs prices to levels not seen in many years. It is not possible at this time to predict with certainty what future volumes or costs may be, but given the volatile price of RINs, the cost of purchasing sufficient RINs to satisfy our obligation could have an adverse impact on our results of operations if we are unable to recover those costs in the sale price of our refined products.

The chart below illustrates the volatility in RINs prices over several quarterly periods, beginning with the first quarter of 20192020 through the secondfirst quarter of 2020.2021.

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Management's Discussion and Analysis


Contractual Obligations
Information regarding our known contractual obligations and commercial commitments of the types described below as of June 30, 2020,March 31, 2021, is set forth in the following table (in millions):
 Payments Due by PeriodPayments Due by Period
 <1 Year 1-3 Years 3-5 Years >5 Years Total<1 Year1-3 Years3-5 Years>5 YearsTotal
Long term debt and notes payable obligations $33.4
 $215.4
 $2,240.5
 $—
 $2,489.3
Long term debt and notes payable obligations$13.4 $902.6 $1,480.8 $— $2,396.8 
Interest(1)
 85.2
 164.2
 97.5
 —
 346.9
Interest(1)
78.9 140.2 62.7 — 281.8 
Operating lease commitments(2)
 53.2
 74.1
 42.9
 54.2
 224.4
Operating lease commitments(2)(7)
Operating lease commitments(2)(7)
47.1 80.6 43.3 55.7 226.7 
Purchase commitments(3)
 359.7
 —
 —
 —
 359.7
Purchase commitments(3)
219.0 (0.2)— — 218.8 
Product financing commitments(4)
Product financing commitments(4)
277.8 — — — 277.8 
Transportation agreements(4)(5)
 106.1
 212.1
 101.4
 62.5
 482.1
135.7 236.9 190.7 96.3 659.6 
J. Aron supply and offtake obligations (5)(6)
 15.5
 238.3
 —
 —
 253.8
15.5 298.8 — — 314.3 
Total $653.1
 $904.1
 $2,482.3
 $116.7
 $4,156.2
Total$787.4 $1,658.9 $1,777.5 $152.0 $4,375.8 
(1) Expected interest payments on debt outstanding at June 30, 2020.March 31, 2021. Floating interest rate debt is calculated using June 30, 2020March 31, 2021 rates. For additional information, see Note 8 to of our condensed consolidated financial statements included in Item 1,1. 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 30, 2020.March 31, 2021.
(3) We have supply agreements 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.
(4) Balances consist of contractual obligations under RINs product financing arrangements.
(5) Balances consist of obligations under agreements with third parties (not including Delek Logistics) for the transportation of crude oil to our refineries.
(5)(6) Balances consists of contractual obligations under the J. Aron Supply and Offtake Agreements, including annual fees and principal obligation for the Baseline Volume Step-Out Liability. For additional information, see Note 7 to of our condensed consolidated financial statements included in Item 1,1. Financial Statements, of this Quarterly Report on Form 10-Q.
(7) Includes an immaterial amount of financing lease cost.
Critical Accounting Policies
The preparation of our condensed consolidated financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and related disclosure of contingent assets and liabilities. The SEC has defined critical accounting policies as those that are both most important to the portrayal of our financial condition and results of operations, and require our most difficult, subjective or complex judgments or estimates. Based on this definition and as further described in our 20192020 Annual Report on Form 10-K, we believe our critical accounting policies include the following: (i) estimating our quarterly inventory adjustments using the last-in, first-out valuation method for the Tyler refinery, (ii) evaluating impairment for property, plant and equipment and definite life intangibles, (iii) evaluating potential impairment of goodwill, (iv) estimating environmental expenditures, and (v) estimating asset retirement obligations.
During Additionally, we have identified the six months ended June 30, 2020, we updated our critical accounting policies to include accounting policies that have become critical as a result of new transactions. Accordingly, we are adding afollowing critical accounting policy that impacts the first quarter of 2021:
Under ASC 740, Accounting for Income Taxes, we use an estimated annual effective tax rate ("AETR") to record income taxes. The development of the estimated AETR involves significant judgment, particularly early in the year and in times of economic uncertainty. In the first quarter of 2021, our estimates of the expected AETR reflected inputs which are subject to judgment including (but not necessarily limited to) the following:
•Forecasted pre-tax GAAP income or loss for the year
•Estimates of expected permanent differences in GAAP income or loss and taxable income or loss for the year
•Forecasted capital expenditures for the year and future years (where such activities were significantly impacted by the recent weather event and can likewise be impacted by unanticipated events)
•Expected applicable jurisdictional tax rates
•Estimated impact of possible deduction and tax credit limitations
•Estimates regarding net operating losses, carryback and carryforward provisions (and limitations) and valuation allowances
All of these inputs are subject to significant judgment and assumptions about future events impacting 2021, some of which are based on historical trends and results, operational plans, and projections regarding future pricing and profitability (where we utilize third party forward curves and pricing sources, where possible, but where expectations regarding capture rates and other factors involve judgment). We also note that, while economic conditions affecting our industry and industry outlooks related to evaluating variable interest entitiesCOVID-19 are stabilizing and improving, there remains a level of uncertainty related to reflect the significant judgment that is involved when determining whether an entity is a variable interest entity ("VIE") and evaluating whether we are the primary beneficiary in connection with our new investment in W2W Holdings LLC. See Note 5 of the condensed consolidated financial statements in Item 1, Financial Statements for discussion of our investment in W2W Holdings LLCCOVID-19 and the related accounting treatment.
Evaluationexpectations for recovery that increases the level of Variable Interest Entities
Our consolidated financial statements include the financial statements of our subsidiaries and VIEs, of which we are the primary beneficiary. We evaluate all legal entities in which we hold an ownership or other pecuniary interest to determine if the entity is a VIE. Variable interests can be contractual, ownership or other pecuniary interests in an entity that changejudgment involved with changes in the fair value of the VIE’s assets. If we are not the primary beneficiary, the general partner or another limited partner may consolidate the VIE, and we record the investment as an equity method investment. Significant judgment is exercised in determining that a legal entity is a VIE and in evaluating whether we are the primary beneficiary in a VIE. Generally, the primary beneficiary is the party that has both the power to direct the activities that most significantly impact the VIE’s economic performance and the right to receive benefits or obligation to absorb losses that could be potentially significant to the VIE. We evaluate the entity’s need for continuing financial support; the equity holder’s lack of a controlling financial interest; and/or if an equity holder’s voting interests are disproportionate to its obligation to absorb expected losses or receive residual returns. We evaluate our interests in a VIE to determine whether we are the primary beneficiary. We use a primarily qualitative analysis to determine if we are deemed to have a controlling financial interest in the VIE, either on a standalone basis or as part of a related party group. We continually monitor our interests in legal entities for changes in the design or activities of an entity and changes in our interests, including our status as the primary beneficiary to determine if the changes require us to revise our previous conclusions.

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Management's Discussion and Analysis


Additionally, due tosome of these assumptions, particularly during the economic and industry impactfirst quarter of 2021. Accordingly, where appropriate, we may consider the COVID-19 Pandemic and the OPEC Production Disputes, we also modified the applicationprobability of certain of our critical accounting policies during and as of the six months ended June 30, 2020 as follows:
Goodwill and Potential Impairment
Our annual goodwill impairment analysis is performed during the fourth quarter of each year. Under Accounting Standards Codification ("ASC") ASC 350, Intangibles - Goodwill and Other, goodwill ofcomponents in determining what we believe to be a reporting unit shall be tested for impairment between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount.
During the six months ended June 30, 2020, we have identified two significant events that adversely affected the global economy and the oil and gas industry. These two events are the COVID-19 Pandemic and the OPEC Production Disputes (previously defined), both of which had the secondary effect of impacting prices of crude oil and refined products as well as supply and demand for crude oil and refined products, and triggered several identified uncertainties, as discussed in the 'Business Overview' section of Management's Discussion and Analysis. Our assessment was performedreasonable estimate based on the events that had occurred through June 30, 2020 and excluded developments that occurred in the subsequent period, including but not limited to government-imposed temporary business closures and voluntary shelter-at-home directives as well as developments in production discussions between global oil producers, and the effect thereof. In order to determine whether these events, including the developments around such events that had occurred through June 30, 2020 and our assumptions about future periods based on those events and related developments, would more likely than not reduce the fair value of a reporting unit below its carrying amount, we performed certain analyses on the most significant inputs in our valuation model to evaluate the impact of these events on the fair value of our reporting units. This included sensitivity analysis and stress testing on certain of our inputs to our valuation model, including the weighted-average cost of capital, the throughput volume, and the crack spread, which is based on the crude and refined product markets. Based on our analyses, we determined that there is not an indicator that fair value is more likely than not to have declined below carrying value as of June 30, 2020.
Additionally, because conditions and events are rapidly changing, we continue to monitor developments with these events and their impact on our valuation. However, there is uncertainty in and around the impact of the COVID-19 Pandemic and the OPEC Production Disputes that have not yet occurred or for existing conditions and events that were in existence as of our reporting date, which may have future ramifications that cannot yet be anticipated. Continuedalso involve the use of significant management judgment. Furthermore, many of our assumptions are inter-relational, where changing one assumption can impact other assumptions (e.g., in terms of the applicability of or sustained adverse changelimitations under various tax code provisions).
The nature of the AETR estimation approach for recording income taxes requires continuous review and adjustment during the year based on actual results, and as better information regarding forecasted results and assumptions becomes available. Significant changes in any of these assumptions or in actual results compared to these factors mayour forecasts and assumptions could cause material changes in our AETR, which could result in potentialcumulative adjustments to reflect the new estimates in future impairment of some or allperiods.
We have developed and utilized methodologies and rationales for the development of our goodwill balance.
Other thanassumptions, subject to internal controls and sensitivity or probability assessments, as described above,appropriate, and we believe our process provides a reasonable basis for all financial statement periods presented, there have been no material modifications toour estimated AETR as well as the applicationincome taxes as of these critical accounting policies or estimates since our most recently filed Annual Report on Form 10-K. See Note 1 ofand for the condensed consolidated financial statements in Item 1, Financial Statements for discussion of updates to our accounting policies.three months ended March 31, 2021.
Non-GAAP Measures
Our management uses certain “non-GAAP” operational measures to evaluate our operating segment performance and non-GAAP financial measures to evaluate past performance and prospects for the future to supplement our GAAP financial information presented in accordance with U.S. GAAP. These financial and operational non-GAAP measures are important factors in assessing our operating results and profitability and include:
•Refining margin - calculated as the difference between net refining revenues and total cost of materials and other;
•Refined product margin - calculated as the difference between net revenues attributable to refined products (produced and purchased) and related cost of materials and other (which is applicable to both the refining segment and the westWest Texas wholesale marketing activities within our logistics segment); and
•Refining margin per barrels sold - calculated as refining margin divided by our average refining sales in barrels per day (excluding purchased barrels) multiplied by 1,000 and multiplied by the number of days in the period.
We believe these non-GAAP operational and financial measures are useful to investors, lenders, ratings agencies and analysts to assess our ongoing performance because, when reconciled to their most comparable GAAP financial measure, they provide improved comparability between periods through the exclusion of certain items that we believe are not indicative of our core operating performance and theythat 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.






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Management's Discussion and Analysis


Non-GAAP Reconciliations
The following table provides a reconciliation of refining margin to the most directly comparable U.S.GAAPU.S. GAAP measure, gross margin:
Reconciliation of refining margin to gross margin
Refining Segment
Three Months Ended March 31,
20212020
Net revenues$1,740.1 $1,727.9 
Cost of sales1,813.4 2,055.5 
Gross margin(73.3)(327.6)
Add back (items included in cost of sales):
Operating expenses (excluding depreciation and amortization)113.6 111.7 
Depreciation and amortization52.1 37.2 
Refining margin$92.4 $(178.7)

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Refining Segment
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Net revenues $1,077.0
 $2,367.8
 $2,804.9
 $4,459.8
Cost of sales 1,062.1
 2,202.9
 3,117.6
 4,024.1
Gross margin 14.9
 164.9
 (312.7) 435.7
Add back (items included in cost of sales):        
Operating expenses (excluding depreciation and amortization) 88.7
 115.0
 200.4
 236.0
Depreciation and amortization 44.8
 33.2
 82.0
 64.3
Refining margin $148.4
 $313.1
 $(30.3) $736.0
Management's Discussion and Analysis


Summary Financial and Other Information
The following table provides summary financial data for Delek:
Summary Statement of Operations Data (in millions)(1)
Consolidated
Three Months Ended
March 31,
20212020
Net revenues$2,392.2 $1,821.2 
Total operating costs and expenses2,472.3 2,182.7 
Operating loss(80.1)(361.5)
Total non-operating expense, net23.6 28.6 
Loss before income tax benefit(103.7)(390.1)
Income tax benefit(12.4)(83.1)
Net loss(91.3)(307.0)
Net income attributed to non-controlling interests7.3 7.4 
Net loss attributable to Delek$(98.6)$(314.4)
Consolidated
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Net revenues $1,535.5
 $2,480.3
 $3,356.7
 $4,680.2
Total operating costs and expenses 1,512.7
 2,346.0
 3,695.4
 4,323.5
Operating income (loss) 22.8
 134.3
 (338.7) 356.7
Total non-operating (income) expense, net (39.8) 25.1
 (11.2) 47.3
Income (loss) before income tax (benefit) expense 62.6
 109.2
 (327.5) 309.4
Income tax (benefit) expense (35.9) 24.6
 (119.0) 70.4
Income (loss) from continuing operations, net of tax 98.5
 84.6
 (208.5) 239.0
Loss from discontinued operations, net of tax —
 (0.8) —
 (0.8)
Net income (loss) 98.5
 83.8
 (208.5) 238.2
Net income attributed to non-controlling interests 10.8
 6.5
 18.2
 11.6
Net income (loss) attributable to Delek $87.7
 $77.3
 $(226.7) $226.6
(1) This information is presented at a summary level for your reference. See the Consolidated Condensed Statements of Income included in Item 1. to this Quarterly Report on Form 10-Q for more detail regarding our results of operations and net loss per share.
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 contribution margin which is defined as net revenues less costs of materials and other and operating expenses, excluding depreciation and amortization.        


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Management's Discussion and Analysis


Results of Operations
Consolidated Results of Operations — Comparison of the Three and Six Months Ended June 30, 2020March 31, 2021 versus the Three and Six Months Ended June 30, 2019March 31, 2020
Net Loss
Q2 2020 vs. Q2 2019
Consolidated net incomeloss for the secondfirst quarter of 20202021 was $98.5$91.3 million compared to $83.8net loss of $307.0 million for the secondfirst quarter of 2019.2020. Consolidated net incomeloss attributable to Delek for the secondfirst quarter of June 30, 2020March 31, 2021 was $87.7$98.6 million, or $1.19$(1.34) per basic share, compared to $77.3net loss of $314.4 million, or $1.01$(4.28) per basic share, for the secondfirst quarter 2019.2020. Explanations for significant drivers impacting net income as compared to the comparable period of the prior year are discussed in the sections below.
YTD 2020 vs. YTD 2019
Consolidatednetlossforthesix months ended June 30, 2020 was $208.5 million compared to net income of $238.2 million for the six months ended June 30, 2019. Consolidated net loss attributable to Delek for the six months ended June 30, 2020 was $226.7 million, or $(3.08) per basic share, compared to net income of $226.6 million, or $2.94 per basic share, for the six months ended June 30, 2019. Explanations for significant drivers impacting net loss as compared to the comparable period of the prior year are discussed in the sections below.
Net Revenues
Q2 2020 vs. Q2 2019
In the secondfirst quarters of 20202021 and 2019,2020, we generated net revenues of $1,535.5$2,392.2 million and $2,480.3$1,821.2 million, respectively, a decreasean increase of $944.8$571.0 million, or 38.1%31.4%. The decreaseincrease in net revenues was primarily driven by the following factors:
•in our refining segment, decreaseswe achieved similar results in the current period as compared to prior year, despite challenges impacting our refineries, including the severe weather event in February 2021, the El Dorado fire and turnaround activities, and the temporary suspension of crude refining unit production at our Krotz Spring refinery; such results were driven by increases in the average price of U.S. Gulf Coast gasoline of 54.7%36.9%, ultra-low sulfur dieselULSD of 53.1%16.0%, and high-sulfur dieselHSD of 59.4% combined with a decrease 10.3%; and
•in barrels sold (both refinedour corporate and purchased)other segment, an increase in wholesale crude activity which began in the second quarter of 1.8 million barrels;2020.

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Management's Discussion and Analysis

Such increases were partially offset by:
•in our retail segment, decreases in fuel sales volumes due to demand slowdown as a result of COVID-19 Pandemic, and reduction in average number of stores, as well as a 31.7% decrease in average price charged per gallon; partially offset by increase in merchandise sales; and
in our logistics segment, decreases in average price per gallon sold combined with decreases in sales volumes in our West Texas marketing operations; partially offset by increased revenues associated with agreements executed in connection with Big Spring Gathering System and Delek Trucking acquisitions.
YTD 2020 vs. YTD 2019
For the six months ended June 30, 2020 and 2019, we generated net revenues of $3,356.7 million and $4,680.2 million, respectively, a decrease of $1,323.5 million, or 28.3%. 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 38.5%, ultra-low sulfur diesel of 37.7%, and high-sulfur diesel of 41.5%;
in our retail segment, decreases in fuel sales volumes due to demand slowdown as a result of COVID-19 Pandemic and reduction in average number of stores, as well as a 17.1% decrease in average price charged per gallon; partially offset by an increase in merchandise sales; and
in our logistics segment, decreasessales as well as a 12.9% increase in average price charged per gallon sold in our West Texas marketing operations; partially offset increased revenues associated with agreements executed in connection with Big Spring Gathering Systemgallon.
Total Operating Costs and Delek Trucking acquisitions, and increased throughputs at our SALA gathering system and Magnolia pipeline.
Expenses
Cost of Materials and Other
Q2 2020 vs. Q2 2019
Cost of materials and other was $1,277.8$2,205.5 million for the secondfirst quarter of 2021 compared to $1,910.6 million for the first quarter of 2020, compared to $2,067.7 million for the second quarteran increase of 2019, a decrease of $789.9$294.9 million, or 38.2%15.4%. The net decreaseincrease in cost of materials and other was primarily driven by the following:
a narrowing of crude oil differentials during the second quarter where the Midland WTI crude oil differential to Brent crude oil was an average discount of $3.58 per barrel compared to $10.88 per barrel in the prior-year period, and the WTI Midland to WTI Cushing discount averaged nearly zero in the second quarter 2020 compared to a discount of $2.24 per barrel in the prior-year period;

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Management's Discussion and Analysis


the net reversal (expense) benefit of $203.1 million related to inventory valuation reserves recognized during the second quarter of 2020 compared to $(0.6) million recognized during the second quarter of 2019, partially offset by a decrease in hedging gains to a loss of $154.4 million recognized during the second quarter of 2020 from a gain of $30.7 million recognized during the second quarter of 2019;
decreases•increases in cost of crude oil feedstocks at the refineries, including a decrease27.3% increase in the average cost of WTI Cushing crude oil and a 29.4% increase in the average cost of WTI Midland crude oil;
•an increase in wholesale crude activity which began in the second quarter of 2020; and
• a decrease in hedging gains to a loss of $57.4 million recognized during the first quarter of 2021 from an averagea gain of $59.80 per barrel$77.9 million recognized during the first quarter of 2020;
These increases were partially offset by:
•the benefit (expense) of $20.4 million related to an averagethe change in pre-tax inventory valuation recognized during the first quarter of $29.77;2021 compared to $(280.8) million recognized during the first quarter of 2020;
•decreases in the average volumes of gasoline and diesel sales volumes and decreasessold, partially offset by increases in the average cost per gallon of gasoline and diesel purchasedsold in the logistics segment;our West Texas marketing operations; and
•a decrease in total retail fuel cost of materials and other attributablegallons sold due to demand slowdown as a reduction in average numberresult of stores and a decreasethe COVID-19 Pandemic, partially offset by an increase in average cost per gallon of $0.98.
YTD 2020 vs. YTD 2019
Cost of materials and other was $3,188.4 million for the six months ended June 30, 2020 compared to $3,767.1 million for the six months ended June 30, 2019, a decrease of $578.7 million, or 15.4%. The net decrease in cost of materials and other was primarily driven by the following:
a narrowing of crude oil differentials during the six months ended June 30, 2020 where the Midland WTI crude oil differential to Brent crude oil was an average discount of $4.26 per barrel compared to $10.49 per barrel in the prior-year period, and the WTI Midland to WTI Cushing discount averaged $0.03 per barrel in the six months ended June 30, 2020 compared to a discount of $1.71 per barrel in the prior-year period;
increases in ethanol RIN prices which averaged $0.34 per RIN in six months ended June 30, 2020 compared to $0.18 per RIN in the prior-year period;
in the logistics segment, decreases in the diesel sales volumes and decreases in the average cost per gallon of gasoline and diesel purchased; and
a decrease in retail fuel cost of materials and other attributable to demand slowdown, a reduction in number of stores and a decrease in average cost per gallon of $0.54.
Such increases were partially offset by the following:
a decrease in hedging gains to a loss of $88.1 million recognized during the six months ended June 30, 2020 from a gain of $50.5 million recognized during the six months ended June 30, 2019.
gallon.
Operating Expenses
Q2 2020 vs. Q2 2019
Operating expenses were $127.8$149.3 million for the secondfirst quarter of 2021 compared to $154.5 million for the first quarter of 2020, compared to $162.3 million for the second quarter of 2019, a decrease of $34.5$5.2 million, or 21.3%3.4%. The decrease in operating expenses was primarily driven by the following:
•a decrease in outside service costs across all segmentsemployee expenses partially due to staff reductions and suspension of matching contributions to our 401(k) match; and
•decreases in contract services partially due to cost reduction measures;
decreasesmeasures continuing in the refining segment related to catalyst and chemical costs, maintenance costs and cost reduction associated with the salefirst quarter of our Bakersfield refinery during the quarter; and2021.
Such decrease in retail operating expenses due to reduction in number of stores.
YTD 2020 vs. YTD 2019
Operating expenses were $282.3 million for the six months ended June 30, 2020 compared to $329.0 million for the six months ended June 30, 2019, an decrease of $46.7 million, or 14.2%. The decrease in operating expenses was primarily drivenoffset by the following:
decrease•an increase in outside serviceutilities costs across all segments due to cost reduction measures;
decreases inprimarily associated with higher natural gas costs during the refining segment related toFebruary 2021 severe freezing conditions that affected most of the regions where we operate, partially offset by lower employee, utilities, catalystsproduction at our El Dorado and maintenance costs; and
decrease in retail operating expenses due to reduction in number of stores.
Krotz Springs refineries.
General and Administrative Expenses
Q2 2020 vs. Q2 2019
General and administrative expenses were $61.7$47.1 million for the secondfirst quarter of 2021 compared to $65.7 million for the first quarter of 2020, compared to $69.5 million for the second quarter of 2019, a decrease of $7.8$18.6 million, or 11.2%28.3%. The decrease in general and administrative expense was primarily driven by the following:

•a decrease in employee expenses partially due to staff reductions, suspension of matching contributions to our 401(k) plan, and reduction of stock-based compensation;
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Management's Discussion and Analysis


•a decrease in contract services due to cost reduction measures; and
•a decrease in loss allowance on a note receivable.
YTD 2020 vs. YTD 2019
General and administrative expenses were $127.4 million and $131.7 million for the six months ended June 30, 2020 and 2019, respectively, a decrease of $4.3 million, or 3.3%. The decrease in general and administrativetravel related expense was primarily driven by the following:
decrease in contract services due to cost reduction measures; andtravel restrictions in place as a result of the COVID-19 Pandemic.
decrease in loss allowance on a note receivable.
These decreases were partially offset by increases in salaried labor, including severance, partially offset by decrease in incentive accrual.
Depreciation and Amortization
Q2 2020 vs. Q2 2019
Depreciation and amortization (included in both cost of sales and other operating expenses) was $59.6$68.5 million for the secondfirst quarter of 2021 compared to $52.6 million for the first quarter of 2020, compared to $50.1 million for the second quarter of 2019, an increase of $9.5$15.9 million, or 19.0%,30.2%. This increase was primarily due to depreciation associated with assets added during the Big Spring refinery turnaround in the first quarter of 2020, the El Dorado turnaroundas well as other refining assets addedplaced in service.
Other Operating Loss (Income), Net
Other operating loss, net increased by $2.6 million in the secondfirst quarter of 2019 and the addition2021 to a loss of the alkylation unit at our Krotz Springs refinery late in the second quarter of 2019.
YTD 2020 vs. YTD 2019
Depreciation and amortization (included in both cost of sales and other operating expenses) was $112.2$1.9 million compared to $96.9income of $0.7 million forin the six months ended June 30, 2020first quarter of 2020.

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Management's Discussion and 2019, respectively, a increase of $15.3Analysis

Non-operating Expenses, Net
Interest Expense
Interest expense decreased by $6.7 million, or 15.8%18.5%, primarily due to depreciation associated with assets added during$29.6 million in the Big Spring refinery turnaroundfirst quarter of 2021 compared to $36.3 million in the first quarter of 2020, the El Dorado turnaround assets added in the second quarter of 2019 and the addition of the alkylation unit at our Krotz Springs refinery late in the second quarter of 2019.
Other Operating Income, Net
Q2 2020 vs. Q2 2019
Other operating income, net increased by $10.6 million in the second quarter of 2020 to income of $14.2 million compared to $3.6 million in the second quarter of 2019.
YTD 2020 vs. YTD 2019
Other operating income, net increased by $13.7 million during the six months ended June 30, 2020 to $14.9 million compared to income of $1.2 million during the six months ended June 30, 2019.
Non-operating Expenses, Net
Interest Expense
Q2 2020 vs. Q2 2019
Interest expense decreased by $3.0 million, or 9.1%, to $29.8 million in the second quarter of 2020 compared to $32.8 million in the second quarter of 2019, primarily driven by the following:
•a decrease in the average effective interest rate of 1.38%1.44% in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 20192020 (where effective interest rate is calculated as interest expense divided by the net average borrowings/obligations outstanding), partially offset by an increase in net average borrowings outstanding (including the obligations under the Supply and Offtake Agreements which have an associated interest charge) of approximately $410.1$221.9 million in the secondfirst quarter of 20202021 (calculated as a simple average of beginning borrowings/obligations and ending borrowings/obligations for the period) compared to the secondfirst quarter of 2019.
YTD 2020 vs. YTD 2019
Interest expense increased by $4.6 million, or 7.5%, to $66.1 million during the six months ended June 30, 2020 compared to $61.5 million during the six months ended June 30, 2019, primarily driven by the following:
an increase in net average borrowings outstanding (including the obligations under the supply and offtake agreements which have an associated interest charge) of approximately $435.3 million during the six months ended June 30, 2020 (calculated as a simple average of beginning borrowings/obligations and ending borrowings/obligations for the period) compared to the six months ended June 30, 2019, partially offset by a decrease in the average effective interest rate of 0.56% during the six months ended June 30, 2020 compared to the

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Management's Discussion and Analysis


six months ended June 30, 2019 (where effective interest rate is calculated as interest expense divided by the net average borrowings/obligations outstanding).2020.
Results from Equity Method Investments
Q2 2020 vs. Q2 2019
We recognized income of $10.7$4.8 million from equity method investments during the secondfirst quarter of 2021, compared to $5.1 million for the first quarter of 2020, a decrease of $0.3 million.
Income Taxes
Income tax expense increased by $70.7 million in the first quarter of 2021 compared to $9.3 million for the secondfirst quarter of 2019, an increase of $1.4 million.
YTD 2020, vs. YTD 2019
During the six months ended June 30, 2020, we recognized income of $15.8 million from equity method investments, compared to $11.9 million for the six months ended June 30, 2019, an increase of $3.9 million. This increase was primarily driven by the following:
the addition•a pre-tax loss of the Red River Joint Venture in May 2019 which contributed income of $4.7$103.7 million in the six months ended June 30, 2020 compared to $2.3 million in the six months ended June 30, 2019; and
an increase in income from our other logistics joint ventures from $4.1 million in the six months ended June 30, 2019 to $7.3 million in the six months ended June 30, 2020.
Such increases were partially offset by losses attributable to our investment in WWP and the WWP Project Financing JV, which is still in the construction period.
Other
During the three and six months ended June 30, 2020, we recognized a gain of $56.9 million on the sale of our non-operating refinery located in Bakersfield, California. See Note 2 of the condensed consolidated financial statements in Item 1, Financial Statements, for additional information.
Q2 2020 vs. Q2 2019
Other income increased $6.4 million, to $1.5 million in secondfirst quarter of 2020 compared to a loss of $4.9 million in the second quarter of 2019.
YTD 2020 vs. YTD 2019
Other income increased $5.9 million, to $2.4 million in the six months ended June 30, 2020, compared to a loss of $3.5 million in the six months ended June 30, 2019.
Income Taxes
Q2 2020 vs. Q2 2019
Income tax expense decreased by $60.5 million in the second quarter of 2020 compared to the second quarter of 2019, primarily driven by the following:
pre-tax income of $62.6 million in the second quarter of 2020,2021, as compared to $109.2$390.1 million for the secondfirst quarter of 2019;2020; and
•a decrease in our effective tax rate which was (57.3)%12.0% for the secondfirst quarter of 2020,2021, compared to 22.5%21.3% for the secondfirst quarter of 20192020 primarily due to the following:
◦changes in valuation allowance for state attributes in the first quarter of 2021 compared to the first quarter of 2020;
◦the reversal of a valuation allowance for deferred tax assets in partnership investments in the first quarter of 2020; and
◦changes in the state income tax footprint for separate state jurisdictions.
◦projected 2020 federal net operating loss carryback to a prior 35% tax rate year creating a 14% rate benefit; and
◦an increase in the estimated annual effective tax rate applied to year-to-date loss for the quarter.
YTD 2020 vs. YTD 2019
Income tax expense decreased by $189.4 million during the six months ended June 30, 2020 compared to the same period for 2019, primarily driven by the following:
pre-tax loss of $327.5 million in the six months ended June 30, 2020, as compared to pre-tax income of $309.4 million for the six months ended June 30, 2019; and
an increase in our effective tax rate which was 36.3% for the six months ended June 30, 2020, compared to 22.8% for the six months ended June 30, 2019 primarily due to the following:
◦projected 2020 federal net operating loss carryback to a prior 35% tax rate year creating a 14% tax rate arbitrage; and
◦reversal of a valuation allowance attributable to book-tax basis differences in partnership investments reported as a discrete benefit in the first quarter.

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Management's Discussion and Analysis


Refining Segment
The tables and charts below set forth certain information concerning our refining segment operations ($ in millions, except per barrel amounts):
Refining Segment Margins
Three Months Ended
March 31,
20212020
Net revenues$1,740.1 $1,727.9 
Cost of materials and other1,647.7 1,906.6 
Refining margin92.4 (178.7)
Operating expenses (excluding depreciation and amortization)113.6 111.7 
Contribution margin$(21.2)$(290.4)
Refining Segment Margins
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Net revenues $1,077.0
 $2,367.8
 $2,804.9
 $4,459.8
Cost of materials and other 928.6
 2,054.7
 2,835.2
 3,723.8
Refining margin 148.4
 313.1
 (30.3) 736.0
Operating expenses (excluding depreciation and amortization) 88.7
 115.0
 200.4
 236.0
Contribution margin $59.7
 $198.1
 $(230.7) $500.0

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 crude which is a global benchmark crude. Global product prices influence product prices in the U.S. As a result, our refineries are influenced by the spread between Brent crude and WTI Midland. The Brent less WTI Midland spread represents the differential between the average per barrel price of Brent crude oil and the average per barrel price of WTI Midland crude oil. A widening of the spread between Brent and WTI Midland will favorably influence our refineries' operating margins. Also, the Krotz Springs refinery is influenced by the spread between Brent crude and LLS. The Brent less LLS spread represents the differential between the average per barrel price of Brent crude oil and the average per barrel price of LLS crude oil. A discount in LLS relative to Brent will favorably influence the Krotz Springs refinery operating margin.
The cost to acquire the refined fuel products we sell to our wholesale customers in our logistics segment and at our convenience stores in our retail segment depends on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined petroleum products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, production levels, the availability of imports, the marketing of competitive fuels and government regulation. Our retail merchandise sales are driven by convenience, customer service, competitive pricing and branding. Motor fuel margin is sales less the delivered cost of fuel and motor fuel taxes, measured on a cents per gallon basis. Our motor fuel margins are impacted by local supply, demand, weather, competitor pricing and product brand.
AsIn 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
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Management's Discussion and Analysis

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

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Management's Discussion and Analysis


Refinery Statistics
Three Months Ended
March 31,
20212020
(Unaudited)
Tyler, TX Refinery
Days in period90 91 
Total sales volume - refined product (average barrels per day)(1)
73,224 74,981 
Products manufactured (average barrels per day):
Gasoline39,560 40,041 
Diesel/Jet27,741 27,403 
Petrochemicals, LPG, natural gas liquids ("NGLs")1,724 1,992 
Other1,471 1,242 
Total production70,496 70,678 
Throughput (average barrels per day):  
   Crude Oil64,753 65,966 
Other feedstocks5,978 5,741 
Total throughput70,731 71,707 
Total refining revenue ($ in millions)$490.0 $419.6 
Cost of materials and other ($ in millions)441.2 566.4 
Total refining margin ($ in millions)$48.8 $(146.8)
Per barrel of refined product sales:  
Tyler refining margin7.41 $(21.51)
Direct operating expenses3.57 $3.73 
Crude Slate: (% based on amount received in period)
WTI crude oil92.6 %92.6 %
East Texas crude oil6.8 %7.4 %
Other0.6 %— %
El Dorado, AR Refinery
Days in period90 91 
Total sales volume - refined product (average barrels per day)(1)
49,711 77,551 
Products manufactured (average barrels per day):
Gasoline17,553 36,407 
Diesel13,973 27,637 
Petrochemicals, LPG, NGLs751 2,061 
Asphalt3,670 6,641 
Other438 972 
Total production36,385 73,718 
Throughput (average barrels per day):  
Crude Oil34,766 71,621 
Other feedstocks1,666 2,643 
Total throughput36,432 74,264 
Total refining revenue ($ in millions)$436.8 $611.9 
Cost of materials and other ($ in millions)450.9 671.5 
Total refining margin ($ in millions)$(14.1)$(59.6)
Per barrel of refined product sales:  
El Dorado refining margin$(3.16)$(8.45)
Direct operating expenses$6.36 $4.42 
Crude Slate: (% based on amount received in period)
WTI crude oil44.0 %34.4 %
Local Arkansas crude oil32.2 %19.2 %
Other23.8 %46.4 %
Refinery Statistics
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
  (Unaudited) (Unaudited)
Tyler, TX Refinery        
Days in period 91
 91
 182
 181
Total sales volume - refined product (average barrels per day)(1)
 69,746
 77,657
 72,364
 73,863
Products manufactured (average barrels per day):        
Gasoline 37,225
 39,997
 38,633
 39,671
Diesel/Jet 27,897
 31,505
 27,650
 29,455
Petrochemicals, LPG, natural gas liquids ("NGLs") 3,216
 3,318
 2,604
 2,690
Other 1,319
 1,654
 1,281
 1,411
Total production 69,657
 76,474
 70,168
 73,227
Throughput (average barrels per day):        
   Crude Oil 64,408
 71,918
 65,187
 68,219
Other feedstocks 5,848
 5,106
 5,648
 5,785
Total throughput 70,256
 77,024
 70,835
 74,004
Per barrel of refined product sales:        
Tyler refining margin (2)
 $32.72
 $12.15
 4.62
 $16.84
Direct operating expenses $3.00
 $3.65
 3.38
 $4.15
Crude Slate: (% based on amount received in period)        
WTI crude oil 94.2% 87.7% 93.3% 89.3%
East Texas crude oil 5.8% 12.3% 6.7% 10.7%
         
El Dorado, AR Refinery        
Days in period 91
 91
 182
 181
Total sales volume - refined product (average barrels per day)(1)
 76,059
 51,002
 76,805
 51,717
Products manufactured (average barrels per day):        
Gasoline 34,346
 21,821
 35,376
 21,159
Diesel 30,060
 17,802
 28,849
 16,633
Petrochemicals, LPG, NGLs 2,063
 551
 2,062
 678
Asphalt 6,049
 6,961
 6,345
 5,899
Other 605
 683
 788
 661
Total production 73,123
 47,818
 73,420
 45,030
Throughput (average barrels per day):  
  
    
Crude Oil 71,406
 47,935
 71,514
 44,542
Other feedstocks 2,369
 359
 2,506
 1,270
Total throughput 73,775
 48,294
 74,020
 45,812
Per barrel of refined product sales:  
  
    
El Dorado refining margin $3.08
 $8.93
 $(2.74) $11.21
Direct operating expenses $3.53
 $5.93
 $3.98
 $6.31
Crude Slate: (% based on amount received in period)        
WTI crude oil 51.4% 43.9% 42.9% 42.6%
Local Arkansas crude oil 14.7% 29.0% 17.0% 28.3%
Other 33.9% 27.1% 40.1% 29.1%


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Management's Discussion and Analysis


Refinery Statistics (continued)
Three Months Ended
March 31,
20212020
(Unaudited)
Big Spring, TX Refinery
Days in period90 91 
Total sales volume - refined product (average barrels per day) (1)
68,699 38,086 
Products manufactured (average barrels per day):
Gasoline32,812 14,607 
Diesel/Jet20,935 9,796 
Petrochemicals, LPG, NGLs3,148 1,381 
Asphalt1,793 850 
Other1,404 480 
Total production60,092 27,114 
Throughput (average barrels per day):  
Crude oil59,758 29,905 
Other feedstocks929 (1,327)
Total throughput60,686 28,578 
Total refining revenue ($ in millions)$502.0 $409.8 
Cost of materials and other ($ in millions)461.2 453.5 
Total refining margin ($ in millions)$40.8 $(43.7)
Per barrel of refined product sales:  
Big Spring refining margin$6.60 $(12.60)
Direct operating expenses$6.43 $7.37 
Crude Slate: (% based on amount received in period)
WTI crude oil62.8 %56.3 %
WTS crude oil37.2 %43.7 %
Krotz Springs, LA Refinery
Days in period90 91 
Total sales volume - refined product (average barrels per day) (1)
24,964 81,016 
Products manufactured (average barrels per day):
Gasoline6,118 29,933 
Diesel/Jet4,003 30,932 
Heavy Oils182 731 
Petrochemicals, LPG, NGLs1,265 3,006 
Other11,216 — 
Total production22,784 64,602 
Throughput (average barrels per day):  
Crude Oil13,554 72,481 
Other feedstocks11,381 (8,383)
Total throughput24,935 64,098 
Total refining revenue ($ in millions)$319.7 $443.6 
Cost of materials and other ($ in millions)305.6 454.6 
Total refining margin ($ in millions)$14.1 $(11.0)
Per barrel of refined product sales:  
Krotz Springs refining margin$6.25 $(1.49)
Direct operating expenses$9.07 $3.43 
Crude Slate: (% based on amount received in period)
WTI Crude81.2 %66.1 %
Gulf Coast Sweet Crude18.8 %33.9 %
Other— %— %
(1)     Includes inter-refinery sales and sales to other segments which are eliminated in consolidation. See tables below.
Refinery Statistics (continued)
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
  (Unaudited) (Unaudited)
Big Spring, TX Refinery        
Days in period 91
 91
 182
 181
Total sales volume - refined product (average barrels per day) (1)
 70,679
 78,158
 54,382
 79,993
Products manufactured (average barrels per day):        
Gasoline 35,789
 36,428
 25,198
 37,657
Diesel/Jet 27,924
 26,638
 18,860
 27,494
Petrochemicals, LPG, NGLs 3,563
 3,679
 2,472
 3,763
Asphalt 2,055
 1,900
 1,452
 1,707
Other 1,208
 1,354
 844
 1,296
Total production 70,539
 69,999
 48,826
 71,917
Throughput (average barrels per day):        
Crude oil 70,327
 72,965
 50,116
 72,649
Other feedstocks 1,483
 (581) 78
 648
Total throughput 71,810
 72,384
 50,194
 73,297
Per barrel of refined product sales:        
Big Spring refining margin $7.88
 $13.77
 $0.71
 $16.00
Direct operating expenses $3.55
 $3.69
 $4.89
 $3.75
Crude Slate: (% based on amount received in period)        
WTI crude oil 83.9% 73.3% 75.1% 76.3%
WTS crude oil 16.1% 26.7% 24.9% 23.7%
         
Krotz Springs, LA Refinery        
Days in period 91
 91
 182
 181
Total sales volume - refined product (average barrels per day) (1)
 61,441
 75,283
 71,229
 76,749
Products manufactured (average barrels per day):        
Gasoline 17,461
 34,498
 24,135
 36,270
Diesel/Jet 21,742
 29,776
 26,337
 30,082
Heavy Oils 215
 1,110
 473
 1,100
Petrochemicals, LPG, NGLs 840
 4,264
 1,923
 5,758
Other 18,871
 —
 14,704
 52
Total production 59,129
 69,648
 67,572 73,262
Throughput (average barrels per day):  
  
    
Crude Oil 59,468
 70,162
 65,975
 71,240
Other feedstocks 1,114
 (1,327) 2,104
 908
Total throughput 60,582
 68,835
 68,079 72,148
Per barrel of refined product sales:  
  
    
Krotz Springs refining margin $(0.64) $9.69
 $(1.12) $10.84
Direct operating expenses $3.53
 $4.39
 $3.47
 $4.14
Crude Slate: (% based on amount received in period)        
WTI Crude 69.7% 61.0% 67.7% 62.0%
Gulf Coast Sweet Crude 30.3% 39.0% 32.3% 38.0%
(1)
Includes inter-refinery sales and sales to other segments which are eliminated in consolidation. See tables below.
(2)
Tyler's refining margin per barrel and the adjusted refining margin per barrel for the second quarter 2020 both reflect the $111.0 million margin benefit of favorable fixed price crude cost transactions during the quarter, but exclude the offsetting realized hedging losses of approximately $(111.0) million. Giving effect to the related hedging losses, the refining margin per barrel would have decreased by $(17.49). Such margin impact was unusually large because of the historic volatility in the crude commodities market during the period.

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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
March 31,
(in barrels per day)20212020
(Unaudited)
Tyler refined product sales to other Delek refineries2,095763 
El Dorado refined product sales to other Delek refineries4451,466 
Big Spring refined product sales to other Delek refineries7281,025 
Krotz Springs refined product sales to other Delek refineries—293 
Inter-refinery Sales
  Three Months Ended June 30, Six Months Ended June 30,
(in barrels per day) 2019 2018 2020 2019
  (Unaudited) (Unaudited)
         
Tyler refined product sales to other Delek refineries 2,190
 914
 1,477 557
El Dorado refined product sales to other Delek refineries 1,074
 988
 446 1,886
Big Spring refined product sales to other Delek refineries 1,269
 653
 1,147 903
Krotz Springs refined product sales to other Delek refineries 197
 10,211
 245 5,530
Refinery Sales to Other Segments
Three Months Ended
March 31,
(in barrels per day)20212020
(Unaudited)
Tyler refined product sales to other Delek segments9223,207 
El Dorado refined product sales to other Delek segments7328 
Big Spring refined product sales to other Delek segments22,11025,112 
Krotz Springs refined product sales to other Delek segments2,007 — 
Refinery Sales to Other Segments
  Three Months Ended June 30, Six Months Ended June 30,
(in barrels per day) 2019 2018 2020 2019
  (Unaudited) (Unaudited)
         
Tyler refined product sales to other Delek segments 1,592
 24
 2,400 281
El Dorado refined product sales to other Delek segments 11
 58
 169 155
Big Spring refined product sales to other Delek segments 20,570
 25,215
 22,841 26,034
Pricing Statistics (average for the period presented)
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
  (Unaudited) (Unaudited)
         
WTI — Cushing crude oil (per barrel) $29.77
 $59.80
 $37.93
 $57.36
WTI — Midland crude oil (per barrel) $29.77
 $57.56
 $37.90
 $55.65
WTS -- Midland crude oil (per barrel) (1)
 $29.61
 $57.93
 $37.69
 $55.95
LLS (per barrel) (1)
 $31.30
 $67.06
 $39.73
 $64.73
Brent crude oil (per barrel) $33.35
 $68.44
 $42.16
 $66.14
         
U.S. Gulf Coast 5-3-2 crack spread (per barrel) - utilizing HSD $3.66
 $15.51
 $6.28
 $14.28
U.S. Gulf Coast 5-3-2 crack spread (per barrel) (1)
 $6.67
 $17.74
 $8.74
 $15.77
U.S. Gulf Coast 3-2-1 crack spread (per barrel) (1)
 $7.08
 $19.24
 $9.32
 $17.23
U.S. Gulf Coast 2-1-1 crack spread (per barrel) (1)
 $2.35
 $9.75
 $5.35
 $8.55
         
U.S. Gulf Coast Unleaded Gasoline (per gallon) $0.81
 $1.79
 $1.02
 $1.66
Gulf Coast Ultra low sulfur diesel (per gallon) $0.91
 $1.94
 $1.19
 $1.91
U.S. Gulf Coast high sulfur diesel (per gallon) $0.73
 $1.80
 $1.04
 $1.78
Natural gas (per MMBTU) (2)
 $1.75
 $2.51
 $1.81
 $2.69
(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 WTI Cushing crude, U.S. Gulf Coast CBOB and U.S. Gulf Coast Pipeline No. 2 heating oil (ultra low sulfur diesel). For our Big Spring refinery, we compare our per barrel refined product margin to the Gulf Coast 3-2-1 crack spread consisting of WTI Cushing crude, Gulf Coast 87 Conventional gasoline and Gulf Coast ultra low sulfur diesel, and for our Krotz Springs refinery, we compare our per barrel refined product margin to the Gulf Coast 2-1-1 crack spread consisting of LLS crude oil, Gulf Coast 87 Conventional gasoline and U.S, Gulf Coast Pipeline No. 2 heating oil (high sulfur diesel). The Tyler refinery's crude oil input is primarily WTI Midland and east Texas, while the El Dorado refinery's crude input is primarily 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.
Pricing Statistics (average for the period presented)
Three Months Ended
March 31,
20212020
(Unaudited)
WTI — Cushing crude oil (per barrel)$58.03 $45.57 
WTI — Midland crude oil (per barrel)$58.90 $45.51 
WTS -- Midland crude oil (per barrel) (1)
$58.77 $44.99 
LLS (per barrel) (1)
$60.18 $47.63 
Brent crude oil (per barrel)$61.17 $50.82 
U.S. Gulf Coast 5-3-2 crack spread (per barrel) - utilizing HSD$10.13 $8.76 
U.S. Gulf Coast 5-3-2 crack spread (per barrel) (1)
$13.57 $10.74 
U.S. Gulf Coast 3-2-1 crack spread (per barrel) (1)
$14.33 $11.41 
U.S. Gulf Coast 2-1-1 crack spread (per barrel) (1)
$7.65 $8.12 
U.S. Gulf Coast Unleaded Gasoline (per gallon)$1.71 $1.25 
Gulf Coast Ultra low sulfur diesel (per gallon)$1.71 $1.47 
U.S. Gulf Coast high sulfur diesel (per gallon)$1.50 $1.36 
Natural gas (per MMBTU) (2)
$2.72 $1.87 
(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 WTI Cushing crude, U.S. Gulf Coast CBOB and U.S. Gulf Coast Pipeline No. 2 heating oil (ultra low sulfur diesel). For our Big Spring refinery, we compare our refined product margin to the Gulf Coast 3-2-1 crack spread consisting of WTI Cushing crude, Gulf Coast 87 Conventional gasoline and Gulf Coast ultra low sulfur diesel, and for our Krotz Springs refinery, we compare our per barrel refined product margin to the Gulf Coast 2-1-1 crack spread consisting of LLS crude oil, Gulf Coast 87 Conventional gasoline and U.S. Gulf Coast Pipeline No. 2 heating oil (high sulfur diesel). The Tyler refinery's crude oil input is primarily WTI Midland and East Texas, while the El Dorado refinery's crude input is primarily 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.
(2)    One Million British Thermal Units ("MMBTU").
(2)
One Million British Thermal Units ("MMBTU").

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Management's Discussion and Analysis


Refining Segment Operational Comparison of the Three and Six Months Ended June 30, 2020March 31, 2021 versus the Three and Six Months Ended June 30, 2019March 31, 2020
Net Revenues
Q2 2020 vs. Q2 2019
Net revenues for the refining segment decreasedincreased by $1,290.8$12.2 million, or 54.5%0.7%, in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 2019,2020, primarily driven by the following:
decreases•increases in the average price of U.S. Gulf Coast gasoline of 54.7%36.9%, ULSD of 53.1%16.0%, and HSD of 59.4%; and10.3%.
decreasesSuch increase was partially offset by the following:
•a decrease in sales volumevolumes of refined product totaling 0.15.2 million barrels, partially due to the temporary suspension of crude refining unit production at our Krotz Springs refinery from November 2020 through February 2021 and related turnaround activities, severe weather impacting our refineries in February 2021, and turnaround at our El Dorado refinery, partially offset by a 1.71.2 million barrel decreaseincrease in purchased product sales due to decreased demand, partially offset byand increased sales volumes at our El DoradoBig Spring refinery which was impacted by scheduledin a turnaround activities in the comparable prior year period.
Net revenues included sales to our retail segment of $40.4$69.7 million and $101.7$68.6 million, sales to our logistics segment of $29.7$65.8 million and $73.2$80.7 million, and sales to our other segment of $5.0$20.1 million and $40.4$9.3 million for the three months ended June 30,March 31, 2021 and March 31, 2020, and June 30, 2019, respectively. We eliminate this intercompany revenue in consolidation.
YTD 2020 vs. YTD 2019
Net revenues for the refining segmentdk-20210331_g9.jpg
Cost of Materials and Other
Cost of materials and other decreased by $1,654.9$258.9 million, or 37.1%13.6%, in the six months ended June 30, 2020first quarter of 2021 compared to the six months ended June 30, 2019,first quarter of 2020, primarily driven by the following:
decreases•a decrease in the average price of U.S. Gulf Coast gasoline of 38.5%, ULSD of 37.7%, and HSD of 41.5%; and
decreases inrefined sales volume of refined product totaling 0.9 million barrels partially due to scheduled turnaround activitiesvolumes at our Big SpringKrotz Springs refinery and El Dorado refinery, partially offset by increased sales volumes at our El Dorado refinery dueBig Spring refinery; and
•the benefit (expense) of $20.6 million related to prior year scheduled turnaround activities, and a 2.5 million barrel decreasethe change in purchased product sales due to decreased demand.
Net revenues included sales to our retail segment of $109.0 million and $191.9 million, sales to our logistics segment of $110.5 million and $152.6 million and sales to our other segment of $14.3 million and $55.4 million forpre-tax inventory valuation recognized during the six months ended June 30, 2020 and 2019, respectively. We eliminate this intercompany revenue in consolidation.
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Cost of Materials and Other
Q2 2020 vs. Q2 2019
Cost of materials and other decreased by $1,126.1 million, or 54.8%, in the secondfirst quarter of 20202021 compared to $(271.6) million recognized during the secondfirst quarter of 2019, primarily driven2020.
These decreases were partially offset by the following:
•increases in the net reversal benefit (expense)cost of $193.7 million relatedWTI Cushing crude oil, from an average of $45.57 per barrel to inventory valuation reserves recognized during the second quarteran average of 2020 compared to $(0.6) million recognized during the second quarter of 2019;$58.03, or 27.3%;
•
decreases in the cost of WTI Cushing crude oil, from an average of $59.80 per barrel to an average of $29.77, or (50.22)%; and
decreases•increases in the cost of WTI Midland crude oil, from an average of $57.56$45.51 per barrel to an average of $29.77,$58.90, or (48.28)%.29.4%; and

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Management's Discussion and Analysis


These decreases were partially offset by the following:
•a decrease in hedging gains to a loss of $146.8$5.0 million recognized during the secondfirst quarter of 20202021 from a gain of $25.6$80.4 million recognized during the secondfirst quarter of 2019.2020.
YTD 2020 vs. YTD 2019
Cost of materials and other decreased by $888.6 million, or 23.9%, during the six months ended June 30, 2020 compared to the six months ended June 30, 2019, primarily driven by the following:
the net reversal (expense) benefit of $(75.3) million related to inventory valuation reserves recognized during the six months ended June 30, 2020 compared to $51.4 million recognized during the six months ended June 30, 2019;
decreases in the cost of WTI Cushing crude oil, from an average of $57.36 per barrel to an average of $37.93, or (33.9)%; and
decreases in the cost of WTI Midland crude oil, from an average of $55.65 per barrel to an average of $37.90, or (31.9)%.
These decreases were partially offset by the following:
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a decrease in hedging gains to a loss of $66.4 million recognized during the six months ended June 30, 2020 from a gain of $44.2 million recognized during the six months ended June 30, 2019;dk-20210331_g3.jpg
Management's Discussion and Analysis
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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 $81.4$95.8 million and $52.2$105.7 million during the secondfirst quarters of 20202021 and 2019, respectively, and $178.1 million and $104.4 million during the six months ended June 30, 2020, and 2019, respectively. We eliminate these intercompany fees in consolidation.
Refining Margin
Q2 2020 vs. Q2 2019
Refining margin decreasedincreased by $164.7$271.1 million, or 52.6%151.7%, in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 2019,2020, primarily driven by the following:
•a 15.6% improvement in the 5-3-2 crack spread (the primary measure for the Tyler refinery and El Dorado refinery);
•a 25.6% improvement in the average Gulf Coast 3-2-1 crack spread (the primary measure for the Big Spring refinery); and
•an increase attributable to the $20.6 million change in pre-tax inventory valuation benefit recognized during the first quarter of 2021 compared to an expense of $271.6 million recognized during the prior year period.
These increases were partially offset by the following:
•a higher percentage of purchased product with a decrease in overall sales volumes;
•a 5.8% decline in the average Gulf Coast 2-1-1 crack spread (the primary measure for the Krotz Springs refinery);
•a narrowing of the average WTI Cushing crude oil differential to WTS crude oil to $0.16$(0.74) per barrel during the secondfirst quarter of 20202021 compared to $1.87$0.58 during the secondfirst quarter of 20192020 and narrowing of the average WTI Midland crude oil differential to WTI Cushing crude oil to nearly zero during the second quarter of 2020 compared to $2.24$(0.87) per barrel during the secondfirst quarter of 2019;2021 compared to $0.06 per barrel during the first quarter of 2020;
•a narrowing of the discount between WTI Midland crude oil and Brent crude oil where, during the secondfirst quarter of 2020,2021, the WTI Midland crude oil differential to Brent crude oil was an average discount of $3.58$2.27 per barrel compared to $10.88$5.31 per barrel during the secondfirst quarter of 2019;2020; and
a 75.9% decline in the average Gulf Coast 2-1-1 crack spread (the primary measure for the Krotz Springs refinery);
a 76.4% decline in the 5-3-2 crack spread (the primary measure for the Tyler refinery and El Dorado refinery);

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Management's Discussion and Analysis


a 63.2% decline in the average Gulf Coast 3-2-1 crack spread (the primary measure for the Big Spring refinery); and
•a decrease in hedging gains to a loss of $146.8$5.0 million recognized during the secondfirst quarter of 20202021 from a gain of $25.6$80.4 million recognized during the secondfirst quarter of 2019.2020.
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Management's Discussion and Analysis

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Operating Expenses
Operating expenses increased by $1.9 million, or 1.7%, in the first quarter of 2021 compared to the first quarter of 2020, primarily driven by the following:
•an increase in utilities costs primarily associated with higher natural gas costs during the February 2021 severe freezing conditions that affected most of the regions where we operate, partially offset by lower production at our Krotz Springs refinery.
Such increase was offset by the following:
•decreases in contract services partially due to cost reduction measures continuing in the first quarter of 2021; and
•decreases in employee related costs partially due to staff reductions made in prior year and suspension of matching contributions to our 401(k) plan.
Contribution Margin
Contribution margin increased by $269.2 million, or a 15.6% improvement in contribution margin percentage, in the first quarter of 2021 compared to the first quarter of 2020, primarily driven by the following:
•an overall increase in the average crack spreads; and
•an increase in reversal benefit related to inventory valuation reserve during the first quarter of 2021 compared to prior year period.
These decreasesincreases were partially offset by the following:
an increase attributable to the reversal benefit of inventory valuation reserve totaling $193.7 million during the second quarter of 2020 compared to prior year period.

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Management's Discussion and Analysis


YTD 2020 vs. YTD 2019
Refining margin decreased by $766.3 million, or 104.1%, in the six months ended June 30, 2020 compared to the six months ended June 30, 2019, primarily driven by the following:
a narrowing of the average discount between WTI Midland crude oil compared to WTI Cushing where, during the six months of 2020, the average WTI Midland crude oil differential to WTI Cushing crude oil was $0.03 per barrel compared to $1.71 during the six months of 2019;
a narrowing of the average discount between WTI Midland crude oil and Brent crude oil where, during the six months of 2020, the WTI Midland crude oil differential to Brent crude oil was an average discount of $4.26 per barrel compared to $10.49 per barrel during the same period of 2019;
a narrowing of the average WTI Cushing crude oil differential to WTS crude oil to $0.24 per barrel during the six months of 2020 compared to $1.41 during the six months of 2019;
a narrowing of the discount between WTI Cushing crude oil compared to Brent where, during the six months of 2020, the average WTI Cushing crude oil differential to Brent crude oil was $4.62 per barrel compared to $8.78 during the six months of 2019;
a 56.0% decline in the 5-3-2 crack spread (the primary measure for the Tyler refinery and El Dorado refinery);
a 45.9% decline in the average Gulf Coast 3-2-1 crack spread (the primary measure for the Big Spring refinery);
a 37.4% decline in the average Gulf Coast 2-1-1 crack spread (the primary measure for the Krotz Springs refinery); and
•
a decrease in hedging gains to $(66.4) million recognized during the six months of 2020 from $44.2 million recognized during the six months of 2019.
These decreases were partially offset by the following:
an increase in reversal benefit of inventory valuation reserve of during the during the six months of 2020 compared to the prior year period.

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Management's Discussion and Analysis


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Operating Expenses
Q2 2020 vs. Q2 2019
Operating expenses decreased by $26.3 million, or 22.9%, in the second quarter of 2020 compared to the second quarter of 2019, primarily driven by the following:
decreases in contractor and maintenance costs partially due to cost reduction measures taken in the second quarter of 2020; and
decreases in catalyst and chemicals costs in the second quarter of 2020, primarily at our Krotz Springs refinery related to scheduled unit downtime; and
reduced costs resulting from the sale of the Bakersfield refinery in May 2020.
YTD 2020 vs. YTD 2019
Operating expenses decreased by $35.6 million, or 15.1%, during the six months ended June 30, 2020 compared to the six months ended June 30, 2019, primarily driven by the following:
decreases in employee related costs primarily related to decrease in incentive plan and workforce optimization to reduce overtime rates;
decreases in utilities and catalyst costs, primarily at our Big Spring and Krotz Springs refineries related to reduced throughput due to turnaround and unit downtime, respectively; and
decreases in contractor and maintenance costs partially due to cost reduction measures taken in the six months of 2020.
Contribution Margin
Q2 2020 vs. Q2 2019
Contribution margin decreased by $138.4 million, or a 2.8% reduction in contribution margin percentage, in the second quarter of 2020 compared to the second quarter of 2019, primarily driven by the following:
the decline of the Midland WTI crude oil differential to Brent crude oil compared to the prior-year period;
an overall decline in the average crack spreads;
an increase in reversal benefit related to inventory valuation reserve of during the second quarter of 2020 compared to prior year period; and
•a narrowing of the discount between WTI Cushing and WTS crude oil compared to the secondfirst quarter of 2019.2020; and
These decreases were partially offset by decreases•an increase in operating expenses across all refineries.


hedging losses compared to the prior-year period.
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Management's Discussion and Analysis


YTD 2029 vs. YTD 2019
Contribution margin decreased by $730.7 million for the six months ended June 30, 2020 compared to the six months ended June 30, 2019, primarily driven by the following:
the decline of the Midland WTI crude oil differential to Brent crude oil compared to the prior-year period;
reduced performance at our Big Spring refinery due to turnaround;
an overall decline in the average crack spreads; ;
an increase in reversal benefit related to inventory valuation reserves recognized during the six months of 2020 compared to the prior year period; and
a narrowing of the discount between WTI Cushing and WTI crude oil compared to the prior-year period.
These decreases were partially offset by decreases in operating expenses across all refineries.

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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):
Logistics Contribution Margin and Operating Information
Three Months Ended
March 31,
20212020
Net revenues$152.9 $163.4 
Cost of materials and other81.1 101.3 
Operating expenses (excluding depreciation and amortization)14.1 14.8 
Contribution margin$57.7 $47.3 
Operating Information:
East Texas - Tyler Refinery sales volumes (average bpd) (1)
71,963 72,650 
Big Spring wholesale marketing throughputs (average bpd)72,927 66,386 
West Texas wholesale marketing throughputs (average bpd)10,138 16,081 
West Texas wholesale marketing margin per barrel$3.42 $2.70 
Terminalling throughputs (average bpd) (2)
144,539 135,329 
Throughputs (average bpd):
Lion Pipeline System:
Crude pipelines (non-gathered)44,118 55,471 
Refined products pipelines to Enterprise Systems26,349 54,106 
SALA Gathering System11,880 34,906
East Texas Crude Logistics System26,075 14,174
Big Spring Gathering Assets (3)
73,724 — 
Plains Connection System108,361 — 
Logistics Contribution Margin and Operating Information
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Net revenues $117.7
 $155.3
 $281.1
 $307.8
Cost of materials and other 43.9
 93.8
 145.2
 190.1
Operating expenses (excluding depreciation and amortization) 12.4
 17.3
 27.2
 33.4
Contribution margin $61.4
 $44.2
 $108.7
 $84.3
Operating Information:        
East Texas - Tyler Refinery sales volumes (average bpd) (1) 
 65,028
 71,123
 68,839
 69,857
Big Spring wholesale marketing throughputs (average bpd) 76,004
 82,964
 71,195
 85,339
West Texas wholesale marketing throughputs (average bpd) 9,143
 11,404
 12,612
 12,418
West Texas wholesale marketing margin per barrel $0.64
 $6.25
 $1.96
 $4.84
Terminalling throughputs (average bpd) (2)
 138,593
 156,922
 136,961
 154,643
Throughputs (average bpd):        
Lion Pipeline System:        
Crude pipelines (non-gathered) 79,066
 37,625
 75,995
 33,179
Refined products pipelines to Enterprise Systems 56,093
 29,893
 55,110
 26,511
SALA Gathering System 9,447
 14,315 13,449
 14,798
East Texas Crude Logistics System 10,275
 19,550 12,224
 18,835
Big Spring Gathering Assets (3)
 105,162
 —
 105,162
 —
(1)Excludes jet fuel and petroleum coke.
(2)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.
(3)The Big Spring Gathering Assets Acquisition was effective March 31, 2020; therefore, there is no comparable activity for first quarter 2020.
(1)
Excludes jet fuel and petroleum coke.
(2)
Consists of terminalling throughputs at our Tyler, Big Spring, Big Sandy and Mount Pleasant, Texas, El Dorado and North Little Rock, Arkansas and Memphis and Nashville, Tennessee terminals.
(3)
Throughputs for the Big Spring Gathering Assets are for the 91 days we owned the assets following the Big Spring Gathering Assets Acquisition effective March 31, 2020.
Logistics Segment Operational Comparison of the Three and Six Months Ended June 30, 2020March 31, 2021 versus the Three and Six Months Ended June 30, 2019March 31, 2020
Net Revenues
Q2 2020 vs. Q2 2019
Net revenues decreased by $37.6$10.5 million, or 24.2%6.4%, in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 2019,2020, primarily driven by the following:
•decreases in the average volumes of gasoline and diesel sold partially offset by decreasesincreases in the average sales prices per gallon of gasoline and diesel sold in our West Texas marketing operations:
◦the average volumes of diesel sold decreased 10.2 million gallons, partially offset by a 1.1 million decrease of gasoline gallons sold.
◦the average sales prices per gallon of diesel and gasoline sold decreased $1.11 per gallon and $1.09 per gallon, respectively.
◦the average volumes of gasoline and diesel sold decreased by 13.9 million gallons and 9.2 million gallons, respectively.
◦the average sales prices of gasoline and diesel sold increased $0.24 per gallon and $0.12 per gallon, respectively.
•decreases in throughputs due to the impact of the severe freezing conditions that affected most of the regions where we operate resulting in lower volumes outside of contractual minimum volume commitments during the three months ended March 31, 2021 when compared to the three months ended March 31, 2020.
•decreases in throughputs at the Paline pipeline due to scheduled pipeline maintenance.
Such decrease was partially offset by the following:
Increased revenues associated with agreements executed in connection with Big Spring Gathering System and Delek Trucking acquisitions, which were effective April 1, 2020 and May 1, 2020, respectively. Refer to Note 4 of the condensed consolidated financial statements in Item 1, Financial Statements, for additional information.
Net revenues included sales to our refining segment of $90.0 million and $61.1 million for the three months ended June 30, 2020 and June 30, 2019, respectively, and sales to our other segment of $0.4 million and $1.1 million for the three months ended June 30, 2020 and 2019, respectively. We eliminate this intercompany revenue in consolidation.

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Management's Discussion and Analysis


YTD 2020 vs. YTD 2019
Net revenues decreased by $26.7 million, or 8.7%, in the six months ended June 30, 2020 compared to the six months ended June 30, 2019, primarily driven by the following:
decreases in the average sales prices per gallon and volumes of diesel gallon sold, partially offset by increases in the average sales volume of gasoline in our West Texas marketing operations:
◦the average volumes of gasoline sold •increased 14.4 million gallons, partially offset by a 11.5 million decrease of diesel gallons sold.
◦the average sales prices per gallon of gasoline and diesel sold decreased $0.47 per gallon and $0.68 per gallon, respectively.
Such decrease was partially offset by the following:
Increased revenues associated with agreements executed in connection with Big Spring Gathering System and Delek Trucking acquisitions, which were effective March 31, 2020 and May 1, 2020, respectively. Refer to Note 4 of the condensed consolidated financial statements in Item 1,1. Financial Statements, for additional information.
•increased revenues at our SALA Gathering System and MagnoliaBig Spring Refinery Crude Pipeline as result of increased throughput(the "BSR Crude Pipeline") during the sixthree months ended June 30, 2020March 31, 2021 when compared to the sixthree months ended June 30, 2019.March 31, 2020 as a result of new contracts executed in the second quarter of 2020.
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Management's Discussion and Analysis

Net revenues included sales to our refining segment of $195.7$95.8 million and $122.1$105.7 million for the sixthree months ended June 30,March 31, 2021 and March 31, 2020, and 2019, respectively, and sales to our other segment of $1.2$0.4 million and $0.9 million for the sixthree months ended June 30,March 31, 2021 and 2020, .respectively. We eliminate this intercompany revenue in consolidation.

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Cost of Materials and Other
Q2 2020 vs. Q2 2019
Cost of materials and other for the logistics segment decreased $49.9$20.2 million, or 53.2%19.9%, in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 20192020 primarily driven by the following:
•decreases in the average diesel volumes sold and average cost per gallon of gasoline and diesel sold, in our West Texas marketing operations:
◦the average volumes of diesel sold decreased 10.2 million gallons, partially offset by 1.1 million increase of gasoline gallons sold.
◦the average cost per gallon of gasoline and diesel sold decreased $0.96 per gallon and $1.03 per gallon, respectively.
Our logistics segment purchased product from our refining segment of $29.7 million and $73.2 million for the three months ended June 30, 2020 and June 30, 2019, respectively. We eliminate these intercompany costs in consolidation.
YTD 2020 vs. YTD 2019
Cost of materials and other for the logistics segment decreased $44.9 million, or 23.6%, in the six months ended June 30, 2020 compared to the six months ended June 30, 2019 primarily driven by the following:
decrease in the average diesel volumes sold, partially offset by decreasesincreases in the average cost per gallon of gasoline and diesel sold in our West Texas marketing operations:

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Management's Discussion and Analysis


◦the average volumes of gasoline and diesel sold decreased 11.5by 13.9 million gallons partially offset by a 14.4and 9.2 million increase ingallons, respectively.
◦the average cost per gallon of gasoline gallons sold.and diesel sold increased $0.27 per gallon and $0.10 per gallon, respectively.
◦the average cost per gallon of gasoline and diesel sold decreased $0.41 per gallon and $0.61 per gallon, respectively.
Our logistics segment purchased product from our refining segment of $110.5$65.8 million and $152.6$80.7 million for the sixthree months ended June 30,March 31, 2021 and March 31, 2020, and June 30, 2019, respectively. We eliminate these intercompany costs in consolidation.

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Management's Discussion and Analysis

Operating Expenses
Q2 2020 vs. Q2 2019
Operating expenses decreased by $4.9$0.7 million, or 28.3%4.7%, in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 2019,2020, driven by the following:
•a decrease in employee and outside services costs due to measures implemented to respond to the COVID-19 Pandemic including delaying non-essential projects; and
decrease in utilities and other variable expenses due to lower production.
YTD 2020 vs. YTD 2019
Operating expenses decreased by $6.2 million, or 18.6%, in the six months ended June 30, 2020 compared to the six months ended June 30, 2019, driven by the following:
decrease in employee and outside services costs due to measures implemented to respond to COVID-19 including delaying non-essential projects;
•lower operating costs associated with allocated contract services pertaining to certain of our assets; and
•decreases in variable expenses such as utilities, maintenance and materials costs due to lower production.throughput; and
•partially offset by the increase in utility costs as a result of significantly higher energy costs during the February 2021 severe freezing conditions that affected most of the regions where we operate.
Contribution Margin
Q2 2020 vs. Q2 2019
Contribution margin increased by $17.2$10.4 million, or 38.9%22.0%, in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 2019,2020, primarily driven by the following:
•an increase in gross margin of $0.72 per barrel in our West Texas marketing operations; and
•increases in revenues associated with agreements executed in connection with Big Spring Gathering System and Delek Trucking acquisitions; and
decreases in operating expenses.acquisitions.
Such increases were partially offset by the following:
•decreases in thegasoline and diesel volumes combined with a decrease in gross margin of $5.61 per barrelsold in our West Texas marketing operations.

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Management's Discussion and Analysis


YTD 2020 vs. YTD 2019
Contributionmarginincreased by $24.4 million, or 28.9%, in the six months ended June 30, 2020 compared to the six months ended June 30, 2019, primarily driven by the following:
increases in revenues associated with agreements executed in connection with Big Spring Gathering System and Delek Trucking acquisitions, Magnolia Pipeline, and SALA Gathering system; and
decreases in operating expenses.
Such increases were partially offset by the following:
decreases in gross margin per barrel sold of $2.88 in our West Texas marketing operations.




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Management's Discussion and Analysis


Retail Segment
The table below sets forth certain information concerning our retail segment operations (gross sales $ in millions):
Retail Contribution Margins
Three Months Ended
March 31,
 20212020
Net revenues$174.8 $178.6 
Cost of materials and other136.5 144.1 
Operating expenses (excluding depreciation and amortization)21.4 22.2 
Contribution margin$16.9 $12.3 
Operating Information
Three Months Ended
March 31,
20212020
Number of stores (end of period)253 253 
Average number of stores253 253 
Average number of fuel stores248 248 
Retail fuel sales$100.1 $106.9 
Retail fuel sales (thousands of gallons)39,765 47,959 
Average retail gallons sold per average number of fuel stores (in thousands)161 194 
Average retail sales price per gallon sold$2.52 $2.23 
Retail fuel margin ($ per gallon) (1)
$0.350 $0.307 
Merchandise sales (in millions)$74.6 $71.7 
Merchandise sales per average number of stores (in millions)$0.3 $0.3 
Merchandise margin %32.7 %31.6 %
Retail Contribution Margins
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Net revenues $165.4
 $224.5
 $344.0
 $421.7
Cost of materials and other 119.6
 182.1
 263.7
 345.5
Operating expenses (excluding depreciation and amortization) 21.5
 24.8
 43.7
 48.4
Contribution margin $24.3
 $17.6
 $36.6
 $27.8
         
Operating Information
Number of stores (end of period) 253
 263
 253
 263
Average number of stores 253
 277
 253
 279
Average number of fuel stores 248
 268
 248
 270
Retail fuel sales $75.9
 $140.8
 $182.9
 $262.7
Retail fuel sales (thousands of gallons) 42,436
 53,743
 90,376
 107,633
Average retail gallons sold per average number of fuel stores (in thousands) 171
 201
 365
 399
Average retail sales price per gallon sold $1.79
 $2.62
 $2.02
 $2.44
Retail fuel margin ($ per gallon) (1)
 $0.445
 $0.292
 $0.372
 $0.246
Merchandise sales (in millions) $89.4
 $83.3
 $161.1
 $158.6
Merchandise sales per average number of stores (in millions) $0.4
 $0.3
 $0.6
 $0.6
Merchandise margin % 30.8% 31.2% 31.1% 31.1%
Same-Store Comparison (2)
Three Months Ended
March 31,
20212020
Change in same-store fuel gallons sold
(17.0)%(8.2)%
Change in same-store merchandise sales4.2 %1.7 %
(1)Retail fuel margin represents gross margin on fuel sales in the retail segment, and is calculated as retail fuel sales revenue less retail fuel cost of sales. The retail fuel margin per gallon calculation is derived by dividing retail fuel margin by the total retail fuel gallons sold for the period.
Same-Store Comparison (2)
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Change in same-store fuel gallons sold 
 (19.7)% 1.7 % (13.9)% 3.1 %
Change in same-store merchandise sales 13.1 % (2.5)% 7.6 % (0.5)%
(2)Same-store comparisons include period-over-period changes in specified metrics for stores that were in service at both the beginning of the earliest period and the end of the most recent period used in the comparison.
(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 period-over-period increases or decreases in specified metrics for stores that were in service at both the beginning of the earliest period and the end of the most recent period used in the comparison.
Retail Segment Operational Comparison of the Three and Six Months Ended June 30, 2020March 31, 2021 versus the Three and Six Months Ended June 30, 2019March 31, 2020
Net Revenue
Q2 2020 vs. Q2 2019
Net revenues for the retail segment decreased by $59.1$3.8 million, or 26.3%2.1%, in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 2019,2020, primarily driven by the following:
•total fuel sales were $75.9$100.1 million in the secondfirst quarter of 2021 compared to $106.9 million in the first quarter of 2020, compared to $140.8 million in the second quarter of 2019, attributable to the following:
◦a decrease in total retail fuel gallons sold for the retail segment to 39.8 million gallons in the first quarter of 2021 compared to 48.0 million gallons in the first quarter of 2020 associated with same-store decrease in fuel volumes of 17.0%, primarily due to demand slowdown as a result of the COVID-19 Pandemic; and
◦a decrease in total retail fuel gallons sold for the retail segment to 42,436 thousand gallons in the second quarter of 2020 compared to 53,743 thousand gallons in the second quarter of 2019 associated with the reduction in average number of stores period over period, and a same-store sales decrease in fuel volumes of 19.7% primarily due to demand slowdown as a result of the COVID-19 Pandemic;

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Management's Discussion and Analysis

◦an offsetting $0.29 increase in average price charged per gallon.
•merchandise sales were $74.6 million in the first quarter of 2021 compared to $71.7 million in the first quarter of 2020 attributable to a same-store sales increase of 4.2%, primarily due to strong sales growth for key categories such as beer, packaged beverages and services.

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◦a $0.83 decrease in average price charged per gallon; and
◦
$5.9 million decrease related to reduction in number of stores period over period.
merchandise sales were $89.4 million in the second quarter of 2020 compared to $83.3 million in the second quarter of 2019 attributable to the following:
◦same-store sales increase of 13.1% primarily due to strong sales growth for key categories such as beer, cigarettes and packaged beverages; and
◦partially offset by a $4.6 million decrease related to reduction in number of stores.
YTD 2020 vs. YTD 2019
Net revenues for the retail segment decreased by $77.7 million, or 18.4%, in the six months ended June 30, 2020 compared to the six months ended June 30, 2019, primarily driven by the following:
total fuel sales were $182.9 million in the six months of 2020 compared to $262.7 million in the six months of 2019, attributable to the following:
◦a decrease in total retail fuel gallons sold of 90,376 thousand gallons in the six months of 2020 compared to 107,633 thousand gallons in the six months of 2019, attributable to a decrease in volumes associated with the reduction in average number of stores period over in addition to same-store sales decline in fuel volumes of 13.9% primarily due to demand slowdown in the second quarter of 2020 as a result of the COVID-19 Pandemic;
◦a $0.42 decrease in average price charged per gallon; and
◦$10.0 million decrease related to reduction in number of stores period over period.
merchandise sales were $161.1 million in the six months of 2020 compared to $158.6 million in the six months of 2019 primarily driven by the following:
◦a same-store sales increase of 7.6%; and
◦partially offset by $10.4 million decrease related to reduction in number of stores period over period.
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Management's Discussion and Analysis


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Cost of Materials and Other
Q2 2020 vs. Q2 2019
Cost of materials and other for the retail segment decreased by $62.5$7.6 million, or 34.3%5.3%, in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 2019,2020, primarily driven by the following:
$7.7 million•a decrease in total retail fuel gallons sold due to reduction in numberdemand slowdown as a result of stores period over period;the COVID-19 Pandemic; and
a decrease•an offsetting increase in average cost per gallon of $0.98$0.25 or 42.0%12.9% applied to fuel sales volumes that decreased period over period.
Our retail segment purchased finished product from our refining segment of $40.4$69.7 million and $101.7$68.6 million for the three months ended June 30, 2020March 31, 2021 and June 30, 2019.March 31, 2020. We eliminate this intercompany cost in consolidation.
YTD 2020 vs. YTD 2019
Cost of materials and other for the retail segment decreased by $81.8 million, or 23.7%, in the six months ended June 30, 2020 compared to the six months ended June 30, 2019, primarily driven by the following:
$16.0 million decrease due to reduction in number of stores period over period; and
a decrease in average cost per gallon of $0.54 or 24.6% applied to fuel sales volumes that decreased slightly period over period.
Our retail segment purchased finished product from our refining segment of $109.0 million and $191.9 million for the six months ended June 30, 2020 and June 30, 2019. We eliminate this intercompany cost in consolidation.
Operating Expenses
Q2 2020 vs. Q2 2019
Operating expenses for the retail segment decreased by $3.3$0.8 million, or 13.3%3.6% in the secondfirst quarter of 2021 compared to the first quarter of 2020 compared toas a result of the second quarterexecution of 2019. This decrease is primarily attributable to a decrease in operating costs associated withvarious cost reduction initiatives throughout the reduction in the number of stores.
YTD 2020 vs. YTD 2019
Operating expenses for the retail segment decreased by $4.7 million, or 9.7% in the six months ended June 30, 2020 compared to the six months ended June 30, 2019. This decrease is primarily attributable to a decrease in operating costs associated with the reduction in the number of stores.

business.
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Management's Discussion and Analysis


Contribution Margin
Q2 2020 vs. Q2 2019
Contribution margin for the retail segment increased by $6.7$4.6 million, or 38.1%37.4%, in the secondfirst quarter of 20202021 compared to the secondfirst quarter of 2019,2020, primarily driven by a $0.153 per gallon4.1% improvement in the retail fuel margin and an increase in merchandise sales, offset by 0.4% decreasean improvement in merchandise margin.
YTD 2020 vs. YTD 2019
Contribution margin for the retail segment increased by $8.8 million, or 31.7%percentage of 1.1%, and a 3.6% reduction in the six months ended June 30, 2020, compared to the six months ended June 30, 2019, primarily driven by a $0.126 per gallon improvement in the retail fuel margin and increase in merchandise sales.

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operating expenses.
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Management's Discussion and Analysis



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Liquidity and Capital Resources
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 March 31, 2021 our total liquidity amounted to $1.5 billion comprised of $635.4 million in unused credit commitments under the Delek Revolving Credit Facility (as defined in Note 8 of the condensed consolidated financial statements in Item 1. Financial Statements), $112.5 million in unused credit commitments under the Delek Logistics Credit Facility (as defined in Note 8 of the condensed consolidated financial statements in Item 1. Financial Statements) and $793.5 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 operational capital expendituresexpenditures. In response to the COVID-19 Pandemic and expect the samedecline in the foreseeable future.oil prices, on November 5, 2020, we announced that we have elected to suspend dividends in order to conserve capital. 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. We continue to monitor 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 any 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 the current COVID-19 Pandemic and oil prices, some of which are beyond our control.
If market conditions were to change, for instance due to the significant decline in oil prices or uncertainty created by the COVID-19 Pandemic, and our revenue was reduced significantly or operating costs were to increase significantly, our cash flows and liquidity could be unfavorably impacted.
As of June 30, 2020,March 31, 2021, 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 Logistics Credit Facility (see Note 8 of the condensed consolidated financial statements in Item 1,1. Financial Statements). After considering the current effect of the significant decline in oil prices and uncertainty created by the COVID-19 Pandemic on our operations, we currently expect to remain in compliance with our existing debt maintenance covenants, though we can provide no assurances, particularly if conditions significantly worsen beyond our ability to predict. Additionally, we were in compliance with incurrence covenants during the quarter ended June 30, 2020March 31, 2021 to the extent that any of our activities triggered these covenants. However, given the
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Management's Discussion and Analysis

uncertainty around economic conditions arising from the COVID-19 Pandemic, it is at least reasonably possible that conditions could change significantly, and that such changes could adversely impact our ability to meet some of these incurrence covenants. 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 payresume paying 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 Wells Fargo Revolving Credit Facility, (seeand for Delek Logistics, under its Delek Logistics Credit Facility (each as defined in Note 8 of the condensed consolidated financial statements in Item 1,1. Financial Statements); the optionallowance to incur an additional $200 million of secured debt under the Wells Fargo Term Loan Credit Facility (see(as defined in Note 8 of the condensed consolidated financial statements in Item 1,1. Financial Statements); 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, as otherwise contemplated and allowed under our incurrence covenants.

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Cash Flows
The following table sets forth a summary of our consolidated cash flows (in millions):
Consolidated
 Three Months Ended March 31,
 20212020
Cash Flow Data:  
Operating activities$(34.3)$(154.1)
Investing activities(46.1)(146.6)
Financing activities86.4 130.3 
Net increase (decrease)$6.0 $(170.4)
Consolidated
  Six Months Ended June 30,
  2020 2019
Cash Flow Data:    
Operating activities $(323.1) $235.4
Investing activities (155.9) (329.4)
Financing activities 372.7
 (33.9)
Net decrease $(106.3) $(127.9)
Cash Flows from Operating Activities
Net cash used in operating activities was $323.1$34.3 million for the sixthree months ended June 30, 2020,March 31, 2021, compared to cash provided by operating activities of $235.4$154.1 million for the comparable period of 2019.2020. Cash receipts from customers and cash payments to suppliers and for salaries decreased resulting in a net $628.8$201.7 million decrease in cash fromused in operating activities mainly due to a decline in the prices and volume of refined product sold.activities. Additionally, cash paid for debt interest increased by $5.7$109.9 million. This decrease was partially offset by a $10.1 million increase in cash received for dividends and $65.9 million decrease in cash paid for taxes.
Cash Flows from Investing Activities
Net cash used in investing activities was $155.9$46.1 million for the first sixthree months of 2020,2021, compared to $329.4$146.6 million in the comparable period of 2019.2020. The decrease in cash flows used in investing activities was primarily due to a $106.9decrease in cash purchases of property, plant and equipment which decreased from $189.2 million decrease in 2020, to $48.3 million in 2021, partially attributable to delaying non-essential projects in light of the COVID-19 Pandemic. Additionally, equity method investment contributions decreased $25.6 million primarily due to contributions made related to our obtaining a 33% membership interest in the Red River Pipeline Joint Venture in May 2019and WWP Project Financing JV for $124.7 million.$8.2 million and $18.9 million, respectively, during the three months ended March 31, 2020. During the sixthree months ended June 30, 2020,March 31, 2021, we contributed $10.5$1.4 million related to our Red River Pipeline Joint Venture and $18.9$0.1 million related to our interest in WWP and WWP Project Financing JV which did not existJV.
These decreases in cash used in investing activities were partially offset by distributions received in the comparable prior year period. Additionally, we received distributions from our WWP Project Financing JV to return excess capital contributions made in the amount of $69.3 million for which there was no comparable activity in the priorcurrent year period. We also received proceeds of $39.9 million from the sale of our Bakersfield refinery in the six months ended June 30, 2020. These decreases in cash used investing activities were partially offset by an increase in cash purchases of property, plant and equipment which increased from $199.9 million in 2019, to $235.4 million in 2020 predominantly attributable to capital expenditures related to turnaround and other sustaining maintenance activities in our refining segment.
Cash Flows from Financing Activities
Net cash provided by financing activities was $372.7$86.4 million for the sixthree months ended June 30, 2020,March 31, 2021, compared to net cash used of $33.9$130.3 million in the comparable 20192020 period. This increasedecrease in cash provided was predominantly due to net proceeds received from long-term revolvers of $231.6$40.9 million during the sixthree months ended June 30, 2020,March 31, 2021, compared to net payments of $85$176.7 million in the comparable 20192020 period. Additionally contributing to this increase
Such decreases were a decrease in repurchases of common stock to $1.9 million for the six months ended June 30, 2020 compared to $104.8 million in the comparable 2019 period due to management suspending our share repurchase program, andpartially offset by an increase in net proceeds from inventory financing arrangements to $59.9$77.9 million for the sixthree months ended June 30, 2020March 31, 2021 compared to $4.2$21.0 million in the comparable 20192020 period. Partially offsetting this increaseAdditionally, cash paid decreased $1.9 million and $23.1 million, respectively, due to suspension of our share repurchase program in the second quarter of 2020 and suspension of dividend payment in the fourth quarter of 2020. Also, there was a decrease in net proceeds received frompayments under our term debt to $153.8of $23.3 million during the sixthree months ended June 30, 2020,March 31, 2021, compared to $217.6$27.9 million in the comparable 20192020 period. During the three months ended March 31, 2020, we also repurchased 451,822 of Delek Logistics limited partner units from an investor for $5.0 million with no comparable activity in the current year period.
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Cash Position and Indebtedness
As of June 30, 2020,March 31, 2021, our total cash and cash equivalents were $849.0$793.5 million and we had total long-term indebtedness of approximately $2,454.9$2,367.8 million. The total long-term indebtedness is net of deferred financing costs and debt discount of $7.0$6.0 million and $27.4$23.0 million, respectively. Additionally, we had letters of credit issued of approximately $204.6$314.6 million. Total unused credit commitments or borrowing base availability, as applicable, under our revolving credit facilities was approximately $795.4$747.9 million. Our total long-term indebtedness consisted of the following:
•an aggregate principal amount of $100.0$50.0 million under the Revolving Credit Facility, due on March 30, 2023, with average borrowing rate of 3.50%;
•an aggregate principal amount of $1,279.5$1,269.8 million under the Term Loan Credit Facility, due on March 30, 2025, with effective interest rate of 3.44%3.61%;
•an aggregate principal amount of $39.8$39.5 million in outstanding borrowings under the Delek Hapoalim Term Loan, due on December 31, 2022, with effective interest rate of 3.61%3.54%;

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•an aggregate principal amount of $750.0$737.5 million under the Delek Logistics Credit Facility, due on September 28, 2023, with average borrowing rate of 2.78%2.45%;
•an aggregate principal amount of $250.0 million under the Delek Logistics Notes, due in 2025, with effective interest rate of 7.22%7.25%; and
•an aggregate principal amount of $50.0 million under the Reliant Bank Revolver, due on June 30, 2022, with fixed interest rate of 4.50%; and
an aggregate principal amount of $20.0 million under the Promissory Notes, due on January 04, 2021, with fixed interest rate of 5.50%.
See Note 8 of the condensed consolidated financial statements in Item 1,1. Financial Statements, for additional information about our separate credit facilities.
Additionally, our obligation under the supply and offtake inventory financing agreements with J. Aron amounted to $314.0$410.7 million at June 30, 2020, $215.0March 31, 2021, $287.1 million of which is due on December 30, 2022, except that a portion (not to exceed $58.8$33.1 million) of this otherwise long-term component is subject to potential earlier payment under the Periodic Price Adjustment provision. See Note 7 of the condensed consolidated financial statements in Item 1,1. Financial Statements, for additional information about our supply and offtake facilities.
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Management's Discussion and Analysis

Capital Spending
A key component of our long-term strategy is our capital expenditure program. Our capital expenditures for the sixthree months ended June 30, 2020March 31, 2021 were $203.3$67.0 million, of which approximately $180.3$57.8 million was spent in our refining segment, $3.7$7.8 million in our logistics segment, $7.5$0.8 million in our retail segment and $11.8$0.6 million at the holding company level. The following table summarizes our actual capital expenditures for the sixthree months ended June 30, 2020March 31, 2021 and planned capital expenditures for the full year 20202021 by operating segment and major category (in millions):
 Full Year
2020 Forecast		 Six Months Ended June 30, 2020Full Year
2021 Forecast		Three Months Ended March 31, 2021
RefiningRefiningRefining
Sustaining maintenance, including turnaround activities $162.7
 $138.6
Sustaining maintenance, including turnaround activities (1)
Sustaining maintenance, including turnaround activities (1)
$115.3 $57.4 
Regulatory 42.8
 41.5
Regulatory4.0 0.4 
Discretionary projects 0.9
 0.2
Discretionary projects0.9 — 
Refining segment total 206.4
 180.3
Refining segment total120.2 57.8 
    
LogisticsLogisticsLogistics
Regulatory 3.0
 1.3
Regulatory8.4 0.5 
Sustaining maintenance 2.7
 0.5
Sustaining maintenance4.7 — 
Discretionary projects 12.5
 1.9
Discretionary projects14.7 7.3 
Logistics segment total 18.2
 3.7
Logistics segment total27.8 7.8 
    
RetailRetailRetail
Regulatory 0.2
 0.2
Regulatory— — 
Sustaining maintenance 2.2
 1.0
Sustaining maintenance2.5 0.6 
Discretionary projects 6.5
 6.3
Discretionary projects2.4 0.2 
Retail segment total 8.9
 7.5
Retail segment total4.9 0.8 
    
OtherOtherOther
Regulatory 0.6
 0.3
Regulatory4.2 0.4 
Sustaining maintenance 0.8
 —
Sustaining maintenance13.2 0.2 
Discretionary projects(1)(2)
 15.1
 11.5
Discretionary projectsDiscretionary projects9.9 — 
Other total 16.5
 11.8
Other total27.3 0.6 
Total capital spending $250.0
 $203.3
Total capital spending$180.2 $67.0 
(1) The forecast excludes a $65 million discretionary project to complete a connector toExcludes potential additional capital expenditures associated with the WWP pipeline, foreffects of Winter Storm Uri and/or the El Dorado fire that are not yet determinable and/or which we have secured pre-approved committed financing from the WWP members.reasonably expect to be covered under our applicable insurance policies and likewise reimbursable by insurance recoveries.
(2) Excludes purchases of rights-of-way in the amount of $2.1 million in 2020.

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Management's Discussion and Analysis


The amount of our capital expenditure budget is subject to change due to unanticipated increases in the cost, scope and completion time for our capital projects. For example, we may experience increases in the cost of and/or timing to obtain necessary equipment required for our continued compliance with government regulations or to complete improvement projects or scheduled maintenance activities. Additionally, the scope and cost of employee or contractor labor expense related to installation of that equipment could exceed our projections. Our capital expenditure budget may also be revised as management continues to evaluate projects for reliability or profitability. As a result of the uncertainties associated with the COVID-19 Pandemic, we have decreased our capital spending forecast for 2020 to $250.0 million, down from the prior forecast as reported in our Annual Report on Form 10-K for the year ended December 31, 2019, of $325.7 million. Projects that are not essential to maintaining the current operations have been suspended and are expected to resume in 2021. We continue to evaluate the adverse effects of the COVID -19 Pandemic, and may further revise our forecast as a result of changing circumstances.
We have no material off-balance sheet arrangements through the date of the filing of this Quarterly Report on Form 10-Q.

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, as filed on February 28, 2020.March 1, 2021.
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 ASC 815,
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Management's Discussion and Analysis

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.

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Management's Discussion and Analysis


The following table sets forth information relating to our open commodity derivative contracts as of June 30, 2020March 31, 2021 ($ in millions):
 Total Outstanding 
Notional Contract Volume by
Year of Maturity
Total OutstandingNotional Contract Volume by Year of Maturity
Contract Description Fair Value Notional Contract Volume 2020 2021 2022 2023Contract DescriptionFair ValueNotional Contract Volume202120222023
Contracts not designated as hedging instruments:            Contracts not designated as hedging instruments:
Crude oil price swaps - long(1)
 $211.4
 63,562,000
 46,043,000
 17,519,000
 —
 —
Crude oil price swaps - long(1)
$62.0 21,106,000 20,176,000 930,000 — 
Crude oil price swaps - short(1)
 (187.2) 65,780,000
 48,066,000
 17,714,000
 —
 —
Crude oil price swaps - short(1)
(64.0)16,784,000 16,784,000 — — 
Inventory, refined product and crack spread swaps - long(1)
 38.7
 79,419,000
 27,054,000
 22,765,000
 22,200,000
 7,400,000
Inventory, refined product and crack spread swaps - long(1)
13.5 59,209,000 29,609,000 22,200,000 7,400,000 
Inventory, refined product and crack spread swaps - short(1)
 (55.6) 78,967,000
 26,602,000
 22,765,000
 22,200,000
 7,400,000
Inventory, refined product and crack spread swaps - short(1)
(9.3)61,755,000 32,155,000 22,200,000 7,400,000 
Natural gas swaps - long(2)
 16.9
 19,927,500
 19,927,500
 —
 —
 —
Natural gas swaps - long(2)
— — — — — 
Natural gas swaps - short(2)
 (27.7) 30,902,500
 30,902,500
 —
 —
 —
Natural gas swaps - short(2)
— — — — — 
RIN commitment contracts - long(3)
 3.5
 44,900,000
 44,900,000
 —
 —
 —
RIN commitment contracts - long(3)
122.2 235,290,749 235,290,749 — — 
RIN commitment contracts - short(3)
 (3.8) 58,500,000
 58,500,000
 —
 —
 —
RIN commitment contracts - short(3)
(11.3)46,317,747 46,317,747 — — 
Total $(3.8) 441,958,000
 301,995,000
 80,763,000
 44,400,000
 14,800,000
Total$113.1 440,462,496 380,332,496 45,330,000 14,800,000 
Contracts designated as cash flow hedging instruments:            
Crude oil price swaps - long(1)
 $—
 —
 —
 —
 —
 —
Crude oil price swaps - short(1)
 —
 —
 —
 —
 —
 —
Inventory, refined product and crack spread swaps - long(1)
 (2.7) 90,000
 90,000
 —
 —
 —
Inventory, refined product and crack spread swaps - short(1)
 4.5
 90,000
 90,000
 —
 —
 —
Total $1.8
 180,000
 180,000
 —
 —
 —
(1)Volume in barrels
(2)Volume in MMBTU
(3)Volume in RINs
Interest Risk Management Activities
We have market exposure to changes in interest rates relating to our outstanding floating rate borrowings, which totaled approximately $2,169.3$2,096.8 million as of June 30, 2020.March 31, 2021. The annualized impact of a hypothetical one percent change in interest rates on our floating rate debt as of June 30, 2020March 31, 2021 would be to change interest expense by approximately $21.7$21.0 million.
Commodity Derivatives Trading Activities
In the first half of 2018, we began enteringWe enter into active trading positions in a variety of commodity derivatives, which include forward physical contracts, swap contracts, and futures contracts. These contracts are classified as held for trading and are recognized at fair value with changes in fair value recognized in the income statement. 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 all had remaining durations of less than one year as of June 30, 2020.

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Management's DiscussionMarch 31, 2021, and Analysis


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 commodity derivative contracts held for trading purposes as of June 30, 2020:March 31, 2021:
Contract Description Less than 1 year
Over the counter forward sales contracts  
Notional contract volume (1)
 722,871
Weighted-average market price (per barrel) $29.25
Contractual volume at fair value (in millions) $21.1
Over the counter forward purchase contracts  
Notional contract volume (1)
 566,083
Weighted-average market price (per barrel) $29.59
Contractual volume at fair value (in millions) $16.7
Contract DescriptionLess than 1 year
Over the counter forward sales contracts (crude)
Notional contract volume (1)
Volume in barrels774,849 
Weighted-average market price (per barrel)$48.22 
Contractual volume at fair value (in millions)$37.4 
Over the counter forward purchase contracts (crude)
Notional contract volume (1)
736,678 
Weighted-average market price (per barrel)$48.23 
Contractual volume at fair value (in millions)$35.5 

(1) Volume in barrels


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Management's Discussion and Analysis

ITEM 4. CONTROLS AND PROCEDURES
Our disclosure controls and procedures are designed to provide reasonable assurance that the information that we are required to disclose in reports we file under the Securities Exchange Act, of 1934, as amended ("the Exchange Act"), is accumulated and appropriately communicated to management. 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 identified in connection with the evaluation required by paragraph (d) of Exchange Act Rules 13a-15 or 15d-15 that occurred during the secondfirst quarter of 20202021 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. Although most of our corporate employees have shifted to a remote working environment due to the COVID-19 pandemic,Pandemic, we have not experienced a material impact to our internal control over financial reporting. We are continually monitoring and assessing the COVID-19 situationPandemic to minimize the impact on the design and operating effectiveness of our internal controls.



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


Part II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
In the ordinary conduct of our business, we are from time to time subject to lawsuits, investigations and claims, including, environmental claims and employee-related matters. Although we cannot predict with certainty the ultimate resolution of lawsuits, investigations and claims asserted against us, including civil penalties or other enforcement actions, we do not believe that any currently pending legal proceeding or proceedings to which we are a party will have a material adverse effect on our business, financial condition or results of operations. See Note 11 to our accompanying condensed consolidated financial statements, which is incorporated by reference in this Item1,Item 1, for additional information. Aside from the disclosure in Note 11, there have been no material developments to the proceedings previously reported in our Annual Report on Form 10-K as amended and filed on February 28, 2020.March 1, 2021.

ITEM 1A. RISK FACTORS
There were no material changes during the sixthree months ended June 30, 2020March 31, 2021 to the risk factors identified in the Company’s fiscal 20192020 Annual Report on Form 10-K, except as noted below.10-K.
The current COVID-19 Pandemic and certain developments in the global oil markets have had, and may continue to have, an adverse impact on our business, our future results of operations and our overall financial performance.
The COVID-19 Pandemic could materially adversely affect our business and operations during 2020 and possibly beyond. In early 2020, global health care systems and economies began to experience strain from the spread of the COVID-19 coronavirus. As the virus spread, global economic activity began to slow and future economic activity was forecast to slow with a resulting forecast of a decline in oil and gas demand. The global pandemic has resulted in a dramatic reduction in airline flights and has reduced the number of cars on the road. Governmental actions in response to the COVID-19 Pandemic have resulted in significant business and operational disruptions, including business closures, supply chain disruptions, travel restrictions, stay-at-home orders, and limitations on the availability and effectiveness of the workforce. These impacts have negatively impacted and will likely continue to negatively impact worldwide economic and commercial activity, financial markets, and demand for and prices of oil and gas products for the foreseeable future. These impacts may also precipitate a prolonged economic slowdown and recession.
In response to the decline in demand, OPEC participating countries agreed to adjust downwards their overall production of crude oil through April 30, 2022, with the agreement to be reassessed in December 2021. These declines have been exacerbated by a production dispute between Russia and the members of OPEC, particularly Saudi Arabia, and the subsequent actions taken by such countries as a result thereof. A sustained reduction in crude oil production will potentially affect the global supply, prices of oil and refined products in our market. Additionally, a significant reduction or freeze in crude oil production in the United States will adversely affect our suppliers and source of crude oil.
Global economic growth drives demand for energy from all sources, including fossil fuels. Should the U.S. and global economies experience weakness, demand for energy may decline. Similarly, should growth in global energy production outstrip demand, excess supplies may arise. Declines in demand and excess supplies may result in accompanying declines in commodity prices and deterioration of our financial position along with our ability to operate profitably and our ability to obtain financing to support operations. With respect to our business, we have experienced periodic declines in demand thought to be associated with slowing economic growth in certain markets, including the effects of the COVID-19 Pandemic, coupled with new oil and gas supplies coming on line and other circumstances beyond our control that resulted in oil and gas supply exceeding global demand which, in turn, resulted in steep declines in prices of oil and natural gas. There can be no assurance as to how low the current price decline will persist or that a recurrence of price weakness will not arise in the future.
The COVID-19 Pandemic has resulted in modifications to our business practices, including limiting employee and contractor presence at certain work locations, limiting travel, and reducing capital expenditures for 2020. We may take further actions as required by government authorities or that we determine are in the best interests of our employees, contractors, customers, suppliers and communities. However, there is no assurance that such measures will be sufficient to mitigate the risks posed by the virus, and our ability to successfully execute our business operations could be adversely impacted. In addition, while we have had no COVID-related impairments to date, the continued effects of the COVID-19 Pandemic could result in impairments of long-lived or indefinite-lived assets, including goodwill, at some point in the future. Such impairment charges could be material.
The full impact of the COVID-19 Pandemic is unknown and is rapidly evolving. The ultimate extent of the impact of COVID-19 on our business, financial condition, results of operation and liquidity will depend largely on future developments, including the duration and spread of the virus outbreak, particularly within the geographic areas where we operate, actions taken by national, state, and local governments and health officials to contain the virus or treat its effects, and the related impact on overall economic activity, all of which are uncertain and cannot be predicted with certainty at this time. The ultimate extent of the impact of the volatile conditions in the oil and gas industry on our business, financial condition, results of operation and liquidity will also depend largely on future developments, including the extent and duration of any price reductions, any additional decisions by OPEC and disputes between the members of OPEC+.

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To the extent COVID-19 and the developments in the global oil markets adversely affects our business, financial condition, results of operation and liquidity, they may also have the effect of heightening many of the other risks described in the “Risk Factors” section included in our Annual Report on Form 10-K for the year ended December 31, 2019 and in this Quarterly Report on Form 10-Q, as those risk factors are amended or supplemented by subsequent Quarterly Reports on Form 10-Q and other reports and documents we file with the SEC after the date hereof.
We are particularly vulnerable to disruptions to our refining operations because our refining operations are concentrated in four facilities.
Because all of our refining operations are concentrated in the Tyler, El Dorado, Big Spring and Krotz Springs refineries, significant disruptions at one of these facilities could have a material adverse effect on our consolidated financial results. Refining segment contribution margin comprised approximately 79.4%, 84.2% and 88.3% of our consolidated contribution margin for the 2019, 2018 and 2017 fiscal years, respectively.
Our refineries consist of many processing units, a number of which have been in operation for many years. These processing units undergo periodic shutdowns, known as turnarounds, during which routine maintenance is performed to restore the operation of the equipment to a higher level of performance. Depending on which units are affected, all or a portion of a refinery's production may be halted or disrupted during a maintenance turnaround. We completed a maintenance turnaround at our El Dorado refinery in 2014 and a shortened turnaround that allowed work to be completed on the majority of the process units in March 2019. In addition, we completed a maintenance turnaround at our Tyler refinery in 2015 and a maintenance turnaround for our Big Spring refinery which began January of 2020. We are also subject to unscheduled down time for unanticipated maintenance or repairs.
Refinery operations may also be disrupted by external factors, such as a suspension of feedstock deliveries, cyber-attacks, a global pandemic such as the recent outbreak of the novel coronavirus, or an interruption of electricity, natural gas, water treatment or other utilities. Other potentially disruptive factors include natural disasters, severe weather conditions, workplace or environmental accidents, interruptions of supply, work stoppages, losses of permits or authorizations or acts of terrorism.
The stockholder rights plan adopted by our Board may impair an attempt to acquire control of Delek.
On March 20, 2020, our Board of Directors adopted a stockholder rights plan and declared a dividend of one preferred share purchase right for each outstanding share of our common stock to stockholders of record on March 30, 2020. In the event that a person or group acquires beneficial ownership of 15% or more of our then-outstanding common stock, subject to certain exceptions, each right would entitle its holder (other than such person or members of such group) to purchase one one-thousandth of a share of Series A Junior Participating Preferred Stock. In addition, at any time after a person or group acquires 15% or more of our common stock (unless such person or group acquires 50% or more), the Board may exchange one share of our common stock for each outstanding right (other than rights owned by such person or group, which would have become void). The stockholder rights plan could make it more difficult for a third party to acquire control of Delek or a large block of our common stock without the approval of our Board of Directors. Unless extended by the Board prior to expiration, the rights will expire on March 19, 2021.
The periodic price adjustment settlements on the J. Aron Supply and Offtake Agreement may affect our liquidity position.
In April 2020, we amended and restated our three Supply and Offtake Agreements to renew and extend the terms to December 30, 2022, with J. Aron having the sole discretion to further extend to May 30, 2025 by providing at least six months prior notice to the current maturity date. As part of this amendment, there were changes to the underlying market index, annual fee, the crude purchase fee, crude roll fees and timing of cash settlements related to periodic price adjustments ("PPA") on the differentials.The PPA are calculated semi-annually on October 01 and May 01 ("re-pricing dates") and will result in cash settlements, (either payments to J. Aron or receipts of additional funds from J. Aron), based on the market value of the underlying commodity differential compared to the contractual differential, subject to a set threshold amount. In the event that the periodic price adjustments are triggered on the re-pricing dates, we may be required to make earlier cash payments within three months following the re-pricing date.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
On November 6, 2018, our Board of Directors authorized a share repurchase program for up to $500.0 million of Delek common stock. Any share repurchases under the repurchase program may be implemented through open market transactions or in privately negotiated transactions, in accordance with applicable securities laws. The timing, price, and size of repurchases will be made at the discretion of management and will depend on prevailing market prices, general economic and market conditions and other considerations. The repurchase program does not obligate us to acquire any particular amount of stock and does not expire. The following table sets forth information with respect to the purchase of shares of our common stock made during the three months ended June 30, 2020 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 30, 2020):
Period Total Number of Shares Purchased Average Price Paid per Share Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs 
Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans
or Programs
April 1 - April 30, 2020 —
 $—
 —
 $229,724,248
May 1 - May 31, 2020 —
 —
 —
 229,724,248
June 1 - June 30, 2020 —
 —
 —
 229,724,248
Total —
 $—
 —
 N/A

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ITEM 5. OTHER INFORMATION
Dividend Declaration
On August 3, 2020, our Board of Directors voted to declare a quarterly cash dividend of $0.31 per share of our common stock, payable on September 3, 2020 to shareholders of record on August 19, 2020.
Executive Employment Agreement
On August 1, 2020, the Company entered into an executive employment agreement with Reuven Spiegel (the "Employment Agreement"). The Employment Agreement amends and replaces the offer letter the Company entered into with Mr. Spiegel in April 2020 in connection with his appointment as Chief Financial Officer. The Employment Agreement has a term expiring December 31, 2023, and provides for the following: an annual base salary of $500,000; the $500,000 cash bonus opportunity set forth in Mr. Spiegel’s offer letter, payable in April 2021; beginning in 2021, an annual bonus opportunity with a target amount of 75% of base salary and a maximum payout opportunity of 200% of the target amount; and, beginning in 2021, annual grants under the Company’s 2016 Long-Term Incentive Plan in an amount of $800,000 per year split evenly between time-vesting restricted stock units (“RSUs”) and performance-based RSUs.
In the event Mr. Spiegel is terminated without cause (as defined in the Employment Agreement) or terminates his employment with good reason (as defined in the Employment Agreement), Mr. Spiegel would be entitled to (i) an amount equal to the sum of his then-current base salary and target annual bonus as in effect immediately before any notice of termination, (ii) the costs of continuing family health insurance coverage for 12 months following termination of employment, (iii) any annual bonus Mr. Spiegel would have otherwise been entitled to if his employment had continued through the end of the bonus year based upon the actual performance of the Company, prorated for the period of actual employment during the bonus year, and paid upon the payment of the annual bonuses to senior executives of the Company pursuant to the Company’s annual bonus programs, and (iv) the immediate vesting of all unvested equity awards as follows: (A) for unvested performance awards, on a prorated basis through the termination of employment based on actual results evaluated after the close of the applicable performance period and payable in a lump sum at the same time as performance awards are paid to executives of the Company generally and (B) for full value equity awards (e.g., restricted stock, restricted stock units and phantom units) and appreciation equity awards (e.g., non-qualified stock options and stock appreciation rights), only to the extent that such awards would have vested if Mr. Spiegel’s employment had continued during a period equal to the lesser of six months following termination of employment or the balance of the term of the Employment Agreement.
If Mr. Spiegel terminates his employment for any reason, other than with good reason or upon his death or disability, and provides at least three months’ advance written notice of termination, Mr. Spiegel would be entitled to an amount equal to 50% of his annual base salary at the time notice is delivered, plus the costs of continuing family health insurance coverage for 12 months following the termination of his employment.
If, within two years of a change in control of the Company (as defined in the Employment Agreement), Mr. Spiegel’s employment is terminated by the Company without cause or he terminates his employment for good reason, Mr. Spiegel would be entitled to receive (i) an amount equal to two times the sum of his then-current base salary and target annual bonus as in effect immediately before any notice of termination, (ii) the costs of continuing family health insurance coverage for 12 months following termination of employment, (iii) any annual bonus Mr. Spiegel would have otherwise been entitled if his employment had continued through the end of the bonus year based upon the actual performance of the Company, prorated for the period of actual employment during the bonus year, and paid upon the payment of the annual bonuses to senior executives of the Company pursuant to the Company’s annual bonus programs, and (iv) the immediate vesting of all unvested equity awards. In addition to the foregoing, Mr. Spiegel would receive an additional $500,000 cash bonus if the change in control occurs before March 10, 2021.
All payments to be made by the Company upon termination as described above are subject to Mr. Spiegel executing a release of claims in favor of the Company. In addition to benefits available to the Company’s senior executive officers generally, the Employment Agreement also provides reimbursement for the reasonable costs of professional preparation of his personal income tax returns, not to exceed $25,000 in any calendar year.
The Employment Agreement includes a noncompetition clause which provides that Mr. Spiegel will not compete with the Company, directly or indirectly, in the territory (as defined in the Employment Agreement) during the term of the Employment Agreement and for one year thereafter. The Employment Agreement also includes non-solicitation provisions with respect to the customers and employees of the Company during the term of the Employment Agreement and for one year thereafter.
The above description of the Employment Agreement does not purport to be complete and is qualified in its entirety by reference to the Employment Agreement itself, a copy of which is filed with this report as Exhibit 10.5 and is incorporated herein in its entirety by reference.




None.
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Exhibits

ITEM 6. EXHIBITS
Exhibit No.Description
Exhibit No.Description
3.1
#
Third Amended and Restated Bylaws of Delek US Holdings, Inc. (incorporated by reference to Exhibit 3.2 of the Company’s Quarterly Report on Form 10-Q filed on May 8, 2020).
10.131.1
#
Second Amendment to the Delek US Holdings, Inc. 2016 Long-Term Incentive Plan, effective as of May 5, 2020 (incorporated by reference to Exhibit 10.3 of the Company’s Quarterly Report on Form 10-Q filed on May 8, 2020).
10.2
Amended and Restated Executive Employment Agreement, dated as of May 8, 2020, by and between Delek US Holdings, Inc. and Ezra Uzi Yemin (incorporated by reference to Exhibit 10.4 of the Company’s Quarterly Report on Form 10-Q filed on May 8, 2020).
10.3
Amended and Restated Executive Employment Agreement, dated April 6, 2020, between Delek US Holdings, Inc. and Avigal Soreq (incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed on April 9, 2020).
10.4
Offer Letter, dated April 6, 2020, between Delek US Holdings, Inc. and Reuven Spiegel (incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed on April 9, 2020).
10.5
#
Executive Employment Agreement, dated August 1, 2020, by and between Delek US Holdings, Inc. and Reuven Spiegel.
10.6
Transportation Services Agreement, dated May 15, 2020 and effective as of May 1, 2020, between Delek Refining, Ltd., Lion Oil Company and DKL Transportation, LLC (incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed on May 18, 2020).
10.7
~

Third Amendment and Restatement of Schedules to Third Amended and Restated Omnibus Agreement, dated and effective as of May 15, 2020 (incorporated by reference to Exhibit 10.2 of the Company’s Form 8-K filed on May 18, 2020).
10.8
Third Incremental Amendment to Term Loan Credit Agreement, dated as of May 19, 2020, among Delek US Holdings, Inc., as borrower, the guarantors party thereto, the lenders party thereto, and Wells Fargo Bank, National Association, as administrative agent (incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed on May 21, 2020).
10.9
~#
Third Amended and Restated Supply and Offtake Agreement, dated as of April 7, 2020, between J. Aron & Company LLC and Alon Refining Krotz Springs, Inc.
10.10
~#
Third Amended and Restated Supply and Offtake Agreement, dated as of April 7, 2020, among J. Aron & Company LLC, Lion Oil Company and Lion Oil Trading & Transportation, LLC.
10.11
~#
Third Amended and Restated Supply and Offtake Agreement, dated as of April 7, 2020, between J. Aron & Company LLC and Alon USA, 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.
101The following materials from Delek US Holdings, Inc.’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2020,March 31, 2021, formatted in Inline XBRL (eXtensible Business Reporting Language): (i) Condensed Consolidated Balance Sheets as of June 30, 2020March 31, 2021 and December 31, 20192020 (Unaudited), (ii) Condensed Consolidated Statements of Income for the three and six months ended June 30,March 31, 2021 and 2020 and 2019 (Unaudited), (iii) Condensed Consolidated Statements of Comprehensive Income for the three and six months ended June 30,March 31, 2021 and 2020 and 2019 (Unaudited), (iv) Condensed Consolidated Statements of Changes in Stockholders' Equity for the three and six months ended June 30,March 31, 2021 and 2020 and 2019 (Unaudited), (v) Condensed Consolidated Statements of Cash Flows for the sixthree months ended June 30,March 31, 2021 and 2020 and 2019 (Unaudited), and (vi) Notes to Condensed Consolidated Financial Statements (Unaudited).
104The cover page from Delek US Holdings, Inc.'s Quarterly Report on Form 10-Q for the quarter ended June 30,March 31, 2020, has been formatted in Inline XBRL.
#Filed herewith
##Furnished herewith
~Certain information contained in these exhibits has been omitted because it is not material and would likely cause competitive harm to the Company if publicly disclosed.


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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.
Delek US Holdings, Inc.
By:  
By:  /s/ Ezra Uzi Yemin  
Ezra Uzi Yemin 
Director (Chairman), President and Chief Executive Officer

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

(Principal Financial and Accounting Officer) 
Dated: AugustMay 6, 2020

2021
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