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 SeptemberJune 30, 20192020
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 1-3876
 _________________________________________________________________
HOLLYFRONTIER CORPORATION
(Exact name of registrant as specified in its charter)
Delaware 75-1056913
(State or other jurisdiction of
incorporation or organization)
 (I.R.S. Employer Identification No.)
2828 N. Harwood, Suite 1300  
Dallas  
Texas 75201
(Address of principal executive offices) (Zip Code)
(214) 871-3555
(Registrant’s telephone number, including area code)

(Former name, former address and former fiscal year, if changed since last report)
Securities registered pursuant to 12(b) of the Securities Exchange Act of 1934:
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common Stock $0.01 par valueHFCNew York Stock Exchange
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 (§232.405 of this chapter) 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  ☒
161,389,721162,015,416 shares of Common Stock, par value $.01 per share, were outstanding on October 25, 2019.July 31, 2020.

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HOLLYFRONTIER CORPORATION
INDEX
 
 Page
  
Forward-Looking Statements
3
  
Definitions
45
  
PART I. FINANCIAL INFORMATION 
  
Item 1. Financial Statements
 
  
Consolidated Balance Sheets
 
SeptemberJune 30, 20192020 (Unaudited) and December 31, 20182019
56
  
Consolidated Statements of Income (Unaudited)
 
Three and NineSix Months Ended SeptemberJune 30, 20192020 and 20182019
67
  
Consolidated Statements of Comprehensive Income (Unaudited)
 
Three and NineSix Months Ended SeptemberJune 30, 20192020 and 20182019
78
  
Consolidated Statements of Cash Flows (Unaudited)
 
NineSix Months Ended SeptemberJune 30, 20192020 and 20182019
89
  
Consolidated Statements of Equity (Unaudited)
 
Three and NineSix Months Ended SeptemberJune 30, 20192020 and 20182019
910
  
Notes to Consolidated Financial Statements (Unaudited)
1112
  
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations
3834
  
Item 3. Quantitative and Qualitative Disclosures About Market Risk
5655
  
Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles
5655
  
Item 4. Controls and Procedures
5857
  
PART II. OTHER INFORMATION
 
  
Item 1. Legal Proceedings
5958
  
Item 1A. Risk Factors
60
  
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
61
  
Item 6. Exhibits
61
  
Index to Exhibits
62
  
Signatures
63

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FORWARD-LOOKING STATEMENTS

References herein to HollyFrontier Corporation (“HollyFrontier”) include HollyFrontier and its consolidated subsidiaries. In accordance with the Securities and Exchange Commission’s (“SEC”) “Plain English” guidelines, this Quarterly Report on Form 10-Q has been written in the first person. In this document, the words “we,” “our,” “ours” and “us” refer only to HollyFrontier and its consolidated subsidiaries or to HollyFrontier or an individual subsidiary and not to any other person with certain exceptions. Generally, the words “we,” “our,” “ours” and “us” include Holly Energy Partners, L.P. (“HEP”) and its subsidiaries as consolidated subsidiaries of HollyFrontier, unless when used in disclosures of transactions or obligations between HEP and HollyFrontier or its other subsidiaries. This document contains certain disclosures of agreements that are specific to HEP and its consolidated subsidiaries and do not necessarily represent obligations of HollyFrontier. When used in descriptions of agreements and transactions, “HEP” refers to HEP and its consolidated subsidiaries.

This Quarterly Report on Form 10-Q contains certain “forward-looking statements” within the meaning of the federal securities laws. All statements, other than statements of historical fact included in this Form 10-Q, including, but not limited to, those under “Results of Operations,” “Liquidity and Capital Resources” and “Risk Management” in Part I, Item 2 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and those in Part II, Item 1 “Legal Proceedings” are forward-looking statements. Forward-looking statements use words such as “anticipate,” “project,” “expect,” “plan,” “goal,” “forecast,” “intend,” “should,” “would,” “could,” “believe,” “may,” and similar expressions and statements regarding our plans and objectives for future operations. These statements are based on management’s beliefs and assumptions using currently available information and expectations as of the date hereof, are not guarantees of future performance and involve certain risks and uncertainties. All statements concerning our expectations for future results of operations are based on forecasts for our existing operations and do not include the potential impact of any future acquisitions. Although we believe that the expectations reflected in these forward-looking statements are reasonable, we cannot assure you that our expectations will prove to be correct. Therefore, actual outcomes and results could materially differ from what is expressed, implied or forecast in these statements. Any differences could be caused by a number of factors including, but not limited to:

the extraordinary market environment and effects of the COVID-19 pandemic, including the continuation of a material decline in demand for refined petroleum products in markets we serve;
risks and uncertainties with respect to the actions of actual or potential competitive suppliers and transporters of refined petroleum products or lubricant and specialty products in our markets;
the demand for and supply of crude oil and refined products;
the spread between market prices for refined products and market prices for crude oil;
the possibility of constraints on the transportation of refined products or lubricant and specialty products;
the possibility of inefficiencies, curtailments or shutdowns in refinery operations or pipelines;pipelines, whether due to infection in the workforce or in response to reductions in demand;
effects of governmental and environmental regulations and policies;policies, including the effects of current restrictions on various commercial and economic activities in response to the COVID-19 pandemic;
the availability and cost of our financing;
the effectiveness of our capital investments and marketing strategies;
our efficiency in carrying out and consummating construction projects;projects, including our ability to complete announced capital projects, such as the conversion of the Cheyenne Refinery to a renewable diesel facility and the construction of the Artesia renewable diesel unit and pretreatment unit, on time and within budget;
our ability to timely obtain or maintain permits, including those necessary for operations or capital projects,
our ability to acquire refined or lubricant product operations or pipeline and terminal operations on acceptable terms and to integrate any existing or future acquired operations;
the possibility of terrorist or cyber attackscyberattacks and the consequences of any such attacks;
general economic conditions;conditions, including uncertainty regarding the timing, pace and extent of an economic recovery in the United States;
further deterioration in gross margins or a prolonged economic slowdown due to the COVID-19 pandemic which could result in an impairment of goodwill and / or additional long-lived asset impairments; and
other financial, operational and legal risks and uncertainties detailed from time to time in our SEC filings.

Cautionary statements identifying important factors that could cause actual results to differ materially from our expectations are set forth in this Form 10-Q, including without limitation the forward-looking statements that are referred to above. This summary discussionWhen considering forward-looking statements, you should be readkeep in conjunction withmind the discussion of the known material risk factors and other cautionary statements set forth under the heading “Risk Factors” included in Item 1A ofin our Annual Report on Form 10-K for the year ended December 31, 20182019 and in conjunction
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with the discussion in this Form 10-Q in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” under the heading “Liquidity and Capital Resources.Resources” and Part II, Item 1A, “Risk Factors.” All forward-looking statements included in this Form 10-Q and all subsequent written or oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these cautionary statements. The forward-looking statements speak only as of the date made and, other than as required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.
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DEFINITIONS

Within this report, the following terms have these specific meanings:

“BPD” means the number of barrels per calendar day of crude oil or petroleum products.

“BPSD” means the number of barrels per stream day (barrels of capacity in a 24 hour period) of crude oil or petroleum products.

“Base oil” is a lubricant grade oil initially produced from refining crude oil or through chemical synthesis that is used in producing lubricant products such as lubricating greases, motor oil and metal processing fluids.

“Black wax crude oil” is a low sulfur, low gravity crude oil produced in the Uintah Basin in Eastern Utah that has certain characteristics that require specific facilities to transport, store and refine into transportation fuels.

“Cracking” means the process of breaking down larger, heavier and more complex hydrocarbon molecules into simpler and lighter molecules.

“Crude oil distillation” means the process of distilling vapor from liquid crudes, usually by heating, and condensing the vapor slightly above atmospheric pressure turning it back to liquid in order to purify, fractionate or form the desired products.

“FCC,” or fluid catalytic cracking, means a refinery process that breaks down large complex hydrocarbon molecules into smaller more useful ones using a circulating bed of catalyst at relatively high temperatures.

“LPG” means liquid petroleum gases.

“Lubricant” or “lube” means a solvent neutral paraffinic product used in commercial heavy duty engine oils, passenger car oils and specialty products for industrial applications such as heat transfer, metalworking, rubber and other general process oil.

“MMBTU” means one million British thermal units.

“Rack back” represents the portion of our Lubricants and Specialty Products business operations that entails the processing of feedstocks into base oils.

“Rack forward” represents the portion of our Lubricants and Specialty Products business operations that entails the processing of base oils into finished lubricants and the packaging, distribution and sale to customers.

“Refinery gross margin” means the difference between average net sales price and average cost per barrel sold. This does not include the associated depreciation and amortization costs.

“RINs” means renewable identification numbers and refers to serial numbers assigned to credits generated from renewable fuel production under the Environmental Protection Agency’s Renewable Fuel Standard (“RFS”) regulations, which require blending renewable fuels into the nation’s fuel supply. In lieu of blending, refiners may purchase these transferable credits in order to comply with the regulations.

“Sour crude oil” means crude oil containing quantities of sulfur greater than 0.4 percent by weight, while “sweet crude oil” means crude oil containing quantities of sulfur equal to or less than 0.4 percent by weight.

“Vacuum distillation” means the process of distilling vapor from liquid crudes, usually by heating, and condensing the vapor below atmospheric pressure turning it back to a liquid in order to purify, fractionate or form the desired products.

“White oil” is an extremely pure, highly-refined petroleum product that has a wide variety of applications ranging from pharmaceutical to cosmetic products.

“WTI” means West Texas Intermediate and is a grade of crude oil used as a common benchmark in oil pricing. WTI is a sweet crude oil and has a relatively low density.


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PART I. FINANCIAL INFORMATION

Item 1.Financial Statements
Item 1. Financial Statements
HOLLYFRONTIER CORPORATION
CONSOLIDATED BALANCE SHEETS
(In thousands, except share data)
 September 30,
2019		 December 31, 2018 June 30,
2020		 December 31, 2019
 (Unaudited)   (Unaudited)  
ASSETS        
Current assets:        
Cash and cash equivalents (HEP: $7,469 and $3,045, respectively)
 $981,856
 $1,154,752
Cash and cash equivalents (HEP: $18,913 and $13,287, respectively)
 $902,509
 $885,162
        
Accounts receivable: Product and transportation (HEP: $16,182 and $12,332, respectively)
 811,355
 635,623
Accounts receivable: Product and transportation (HEP: $14,929 and $18,732, respectively)
 540,818
 834,771
Crude oil resales 28,476
 36,078
 52,567
 44,914
 839,831
 671,701
 593,385
 879,685
Inventories: Crude oil and refined products 1,429,911
 1,166,404
 977,851
 1,282,789
Materials, supplies and other (HEP: $883 and $858, respectively)
 207,148
 187,975
Materials, supplies and other (HEP: $935 and $833, respectively)
 195,850
 191,413
 1,637,059
 1,354,379
 1,173,701
 1,474,202
Income taxes receivable 23,591
 34,040
 77,729
 5,478
Prepayments and other (HEP: $3,896 and $3,452, respectively)
 50,429
 81,507
Prepayments and other (HEP: $6,970 and $6,795, respectively)
 56,210
 61,662
Total current assets 3,532,766
 3,296,379
 2,803,534
 3,306,189
        
Properties, plants and equipment, at cost (HEP: $2,042,185 and $2,058,388, respectively)
 7,134,025
 6,780,980
Less accumulated depreciation (HEP: $(535,215) and $(489,217), respectively)
 (2,336,637) (2,098,446)
Properties, plants and equipment, at cost (HEP: $2,053,174 and $2,047,674, respectively)
 7,052,866
 7,237,297
Less accumulated depreciation (HEP: $(584,651) and $(552,786), respectively)
 (2,567,686) (2,414,585)
 4,797,388
 4,682,534
 4,485,180
 4,822,712
Operating lease right-of-use assets (HEP: $3,454)
 453,377
 —
Operating lease right-of-use assets (HEP: $3,377 and $2,652, respectively)
 390,497
 467,109
        
Other assets: Turnaround costs 405,043
 339,861
 359,203
 521,278
Goodwill (HEP: $312,873 and $314,229, respectively)
 2,370,406
 2,246,435
Intangibles and other (HEP: $166,743 and $176,291, respectively)
 632,348
 429,392
Goodwill (HEP: $312,873 and $312,873, respectively)
 2,373,912
 2,373,907
Intangibles and other (HEP: $350,056 and $319,569, respectively)
 651,494
 673,646
 3,407,797
 3,015,688
 3,384,609
 3,568,831
Total assets $12,191,328
 $10,994,601
 $11,063,820
 $12,164,841
        
LIABILITIES AND EQUITY        
Current liabilities:        
Accounts payable (HEP: $12,809 and $16,723, respectively)
 $1,229,767
 $872,627
Accounts payable (HEP: $14,888 and $18,050, respectively)
 $870,695
 $1,215,555
Income taxes payable 18,782
 17,636
 18,759
 27,965
Operating lease liabilities (HEP: $5,384)
 99,622
 —
Accrued liabilities (HEP: $28,669 and $27,240, respectively)
 357,175
 277,892
Operating lease liabilities (HEP: $3,766 and $3,608, respectively)
 102,336
 104,415
Accrued liabilities (HEP: $30,886 and $30,418, respectively)
 341,252
 337,993
Total current liabilities 1,705,346
 1,168,155
 1,333,042
 1,685,928
        
Long-term debt (HEP: $1,431,869 and $1,418,900, respectively)
 2,425,234
 2,411,540
Noncurrent operating lease liabilities (HEP: $71,022)
 355,410
 —
Deferred income taxes (HEP: $423 and $488, respectively)
 916,520
 722,576
Other long-term liabilities (HEP: $60,482 and $63,534, respectively)
 247,455
 233,271
Long-term debt (HEP: $1,486,648 and $1,462,031, respectively)
 2,480,746
 2,455,640
Noncurrent operating lease liabilities (HEP: $70,167 and $72,000, respectively)
 318,955
 364,420
Deferred income taxes (HEP: $432 and $424, respectively)
 765,572
 889,270
Other long-term liabilities (HEP: $58,351 and $59,021, respectively)
 250,994
 260,157
        
Equity:        
HollyFrontier stockholders’ equity:        
Preferred stock, $1.00 par value – 5,000,000 shares authorized; none issued —
 —
 —
 —
Common stock $.01 par value – 320,000,000 shares authorized; 256,036,760 and 256,036,788 shares issued as of September 30, 2019 and December 31, 2018, respectively 2,560
 2,560
Common stock $.01 par value – 320,000,000 shares authorized; 256,042,554 shares issued as of June 30, 2020 and December 31, 2019 2,560
 2,560
Additional capital 4,224,770
 4,196,125
 4,215,894
 4,204,547
Retained earnings 4,740,677
 4,196,902
 4,148,390
 4,744,120
Accumulated other comprehensive income 17,217
 13,623
 2,225
 14,774
Common stock held in treasury, at cost – 94,174,173 and 83,915,297 shares as of September 30, 2019 and December 31, 2018, respectively (2,965,016) (2,490,639)
Common stock held in treasury, at cost – 94,144,334 and 94,196,029 shares as of June 30, 2020 and December 31, 2019, respectively (2,986,487) (2,987,808)
Total HollyFrontier stockholders’ equity 6,020,208
 5,918,571
 5,382,582
 5,978,193
Noncontrolling interest 521,155
 540,488
 531,929
 531,233
Total equity 6,541,363
 6,459,059
 5,914,511
 6,509,426
Total liabilities and equity $12,191,328
 $10,994,601
 $11,063,820
 $12,164,841

Parenthetical amounts represent asset and liability balances attributable to Holly Energy Partners, L.P. (“HEP”) as of SeptemberJune 30, 20192020 and December 31, 20182019. HEP is a variable interest entity.

See accompanying notes.
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HOLLYFRONTIER CORPORATION
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
(In thousands, except per share data)

 Three Months Ended
September 30,		 Nine Months Ended
September 30,		 Three Months Ended
June 30,		 Six Months Ended
June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
                
Sales and other revenues $4,424,828
 $4,770,799
 $13,104,690
 $13,370,462
 $2,062,930
 $4,782,615
 $5,463,475
 $8,679,862
Operating costs and expenses:                
Cost of products sold (exclusive of depreciation and amortization):                
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) 3,403,767
 3,752,234
 10,307,856
 10,695,275
 1,576,996
 3,704,884
 4,270,722
 6,904,089
Lower of cost or market inventory valuation adjustment 34,062
 17,837
 (150,483) (192,927) (269,904) 47,801
 290,560
 (184,545)
 3,437,829
 3,770,071
 10,157,373
 10,502,348
 1,307,092
 3,752,685
 4,561,282
 6,719,544
Operating expenses (exclusive of depreciation and amortization) 345,578
 317,196
 1,010,422
 933,699
 303,359
 333,252
 631,704
 664,844
Selling, general and administrative expenses (exclusive of depreciation and amortization) 87,626
 71,130
 260,977
 204,469
 75,369
 85,317
 163,106
 173,351
Depreciation and amortization 127,016
 108,885
 375,345
 323,605
 130,178
 126,908
 270,753
 248,329
Goodwill impairment —
 —
 152,712
 —
Long-lived asset and goodwill impairments 436,908
 152,712
 436,908
 152,712
Total operating costs and expenses 3,998,049
 4,267,282
 11,956,829
 11,964,121
 2,252,906
 4,450,874
 6,063,753
 7,958,780
Income from operations 426,779
 503,517
 1,147,861
 1,406,341
Income (loss) from operations (189,976) 331,741
 (600,278) 721,082
Other income (expense):                
Earnings of equity method investments 1,334
 1,114
 5,217
 4,127
 2,156
 1,783
 3,870
 3,883
Interest income 6,164
 5,136
 17,127
 10,660
 1,506
 4,588
 5,579
 10,963
Interest expense (36,027) (32,399) (106,938) (97,446) (32,695) (34,264) (55,334) (70,911)
Gain on foreign currency transactions 395
 281
 4,873
 5,516
Gain on sales-type leases 33,834
 —
 33,834
 —
Loss on early extinguishment of debt —
 —
 (25,915) —
Gain (loss) on foreign currency transactions 2,285
 2,213
 (1,948) 4,478
Other, net 2,356
 741
 3,005
 3,451
 1,572
 92
 3,422
 649
 (25,778) (25,127) (76,716) (73,692) 8,658
 (25,588) (36,492) (50,938)
Income before income taxes 401,001
 478,390
 1,071,145
 1,332,649
Income tax expense:        
Income (loss) before income taxes (181,318) 306,153
 (636,770) 670,144
Income tax expense (benefit):        
Current 58,255
 70,595
 176,903
 216,529
 (65,607) 63,364
 (77,047) 118,648
Deferred 44,766
 45,663
 102,959
 102,213
 34,696
 25,972
 (116,030) 58,193
 103,021
 116,258
 279,862
 318,742
 (30,911) 89,336
 (193,077) 176,841
Net income 297,980
 362,132
 791,283
 1,013,907
Net income (loss) (150,407) 216,817
 (443,693) 493,303
Less net income attributable to noncontrolling interest 36,167
 19,666
 79,500
 57,843
 26,270
 19,902
 37,607
 43,333
Net income attributable to HollyFrontier stockholders $261,813
 $342,466
 $711,783
 $956,064
Earnings per share attributable to HollyFrontier stockholders:        
Net income (loss) attributable to HollyFrontier stockholders $(176,677) $196,915
 $(481,300) $449,970
Earnings (loss) per share attributable to HollyFrontier stockholders:        
Basic $1.60
 $1.95
 $4.23
 $5.42
 $(1.09) $1.16
 $(2.97) $2.64
Diluted $1.58
 $1.93
 $4.20
 $5.37
 $(1.09) $1.15
 $(2.97) $2.62
Average number of common shares outstanding:                
Basic 163,676
 175,097
 167,935
 175,865
 161,889
 169,356
 161,882
 170,100
Diluted 165,011
 176,927
 169,125
 177,557
 161,889
 170,547
 161,882
 171,264

See accompanying notes.
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HOLLYFRONTIER CORPORATION
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
(In thousands)
 
 Three Months Ended
September 30,		 Nine Months Ended
September 30,		 Three Months Ended
June 30,		 Six Months Ended
June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
                
Net income $297,980
 $362,132
 $791,283
 $1,013,907
Net income (loss) $(150,407) $216,817
 $(443,693) $493,303
Other comprehensive income (loss):                
Foreign currency translation adjustment (9,311) 8,325
 4,212
 (15,118) 11,710
 9,160
 (9,876) 13,523
Hedging instruments:                
Change in fair value of cash flow hedging instruments (1,989) 4,161
 12,909
 (4,242) 1,513
 (693) (5,235) 14,897
Reclassification adjustments to net income on settlement of cash flow hedging instruments (5,573) 1,631
 (12,537) 6,038
Reclassification adjustments to net income (loss) on settlement of cash flow hedging instruments 5,401
 (5,321) (1,175) (6,963)
Net unrealized gain (loss) on hedging instruments (7,562) 5,792
 372
 1,796
 6,914
 (6,014) (6,410) 7,934
Pension and other post-retirement benefit obligations:        
Actuarial gain (loss) on pension plans —
 72
 (45) —
Actuarial gain on post-retirement healthcare plans —
 2
 3
 —
Net change in pension and other post-retirement benefit obligations —
 74
 (42) —
Other comprehensive income (loss) before income taxes (16,873) 14,117
 4,584
 (13,322) 18,624
 3,220
 (16,328) 21,457
Income tax expense (benefit) (3,888) 3,234
 990
 (2,677) 4,250
 416
 (3,779) 4,878
Other comprehensive income (loss) (12,985) 10,883
 3,594
 (10,645) 14,374
 2,804
 (12,549) 16,579
Total comprehensive income 284,995
 373,015
 794,877
 1,003,262
Total comprehensive income (loss) (136,033) 219,621
 (456,242) 509,882
Less noncontrolling interest in comprehensive income 36,167
 19,666
 79,500
 57,843
 26,270
 19,902
 37,607
 43,333
Comprehensive income attributable to HollyFrontier stockholders $248,828
 $353,349
 $715,377
 $945,419
Comprehensive income (loss) attributable to HollyFrontier stockholders $(162,303) $199,719
 $(493,849) $466,549

See accompanying notes.

Table of Content

HOLLYFRONTIER CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
(In thousands)
 Nine Months Ended September 30, Six Months Ended June 30,
 2019 2018 2020 2019
Cash flows from operating activities:        
Net income $791,283
 $1,013,907
Net income (loss) $(443,693) $493,303
Adjustments to reconcile net income to net cash provided by operating activities:        
Depreciation and amortization 375,345
 323,605
 270,753
 248,329
Goodwill impairment 152,712
 —
Long-lived asset and goodwill impairments 436,908
 152,712
Lower of cost or market inventory valuation adjustment (150,483) (192,927) 290,560
 (184,545)
Earnings of equity method investments, inclusive of distributions 280
 463
 (1,298) —
Loss on early extinguishment of debt 25,915
 —
Gain on sales-type leases (33,834) —
(Gain) loss on sale of assets 202
 (52) (357) 73
Deferred income taxes 102,959
 102,213
 (116,030) 58,193
Equity-based compensation expense 30,635
 26,096
 14,289
 21,562
Change in fair value – derivative instruments 19,880
 (3,007) (9,377) 31,454
(Increase) decrease in current assets:        
Accounts receivable (116,793) (136,764) 281,011
 (72,300)
Inventories (47,409) (33,856) (764) (6,708)
Income taxes receivable 13,704
 27,792
 (72,382) (26,835)
Prepayments and other 17,710
 (14,089) 9,704
 14,020
Increase (decrease) in current liabilities:        
Accounts payable 321,537
 (37,160) (314,892) 292,893
Income taxes payable 808
 76,277
 (9,268) 7,826
Accrued liabilities 54,779
 84,328
 3,340
 38,003
Turnaround expenditures (152,431) (114,593) (49,248) (110,273)
Other, net (3,314) 7,664
 27,965
 11,843
Net cash provided by operating activities 1,411,404
 1,129,897
 309,302
 969,550
        
Cash flows from investing activities:        
Additions to properties, plants and equipment (171,229) (167,967) (98,996) (102,717)
Additions to properties, plants and equipment – HEP (23,828) (41,111) (30,740) (17,752)
Purchase of Sonneborn, net of cash acquired (662,665) —
 —
 (662,665)
Purchase of Red Giant Oil, net of cash acquired —
 (54,088)
Investment in equity company - HEP (2,400) —
Other, net 958
 3,999
 470
 825
Net cash used for investing activities (856,764) (259,167) (131,666) (782,309)
        
Cash flows from financing activities:        
Borrowings under credit agreements 269,500
 256,000
 168,000
 175,000
Repayments under credit agreements (257,000) (347,000) (138,500) (156,500)
Proceeds from issuance of common units - HEP —
 114,887
Proceeds from issuance of senior notes - HEP 500,000
 —
Redemption of senior notes - HEP (522,500) —
Purchase of treasury stock (471,976) (177,710) (1,243) (266,996)
Dividends (168,008) (175,921) (114,430) (113,508)
Distributions to noncontrolling interest (100,095) (93,128)
Distributions to noncontrolling interests (51,008) (66,703)
Contributions from noncontrolling interests 13,263
 —
Payments on finance leases (1,158) —
 (843) (783)
Deferred financing costs (8,714) —
Other, net (600) (544) 456
 (374)
Net cash used for financing activities (729,337) (423,416) (155,519) (429,864)
        
Effect of exchange rate on cash flow 1,801
 (2,394) (4,770) 2,515
        
Cash and cash equivalents:        
Increase (decrease) for the period (172,896) 444,920
 17,347
 (240,108)
Beginning of period 1,154,752
 630,757
 885,162
 1,154,752
End of period $981,856
 $1,075,677
 $902,509
 $914,644
        
Supplemental disclosure of cash flow information:        
Cash paid during the period for:        
Interest $(93,929) $(89,553) $(64,003) $(67,620)
Income taxes, net $(163,232) $(112,520) $(4,738) $(138,587)

See accompanying notes.

HOLLYFRONTIER CORPORATION
CONSOLIDATED STATEMENTS OF EQUITY
(Unaudited)
(In thousands)thousands except per share data)

 HollyFrontier Stockholders' Equity    
 Common Stock  Additional Capital Retained Earnings Accumulated Other Comprehensive Income Treasury stock Non-controlling Interest Total
Equity
  
Balance at December 31, 2018$2,560
 $4,196,125
 $4,196,902
 $13,623
 $(2,490,639) $540,488
 $6,459,059
Net income—
 —
 253,055
 —
 —
 23,431
 276,486
Dividends ($0.33 declared per common share)—
 —
 (56,849) —
 —
 —
 (56,849)
Distributions to noncontrolling interest holders—
 —
 —
 —
 —
 (33,673) (33,673)
Other comprehensive income, net of tax—
 —
 —
 13,775
 —
 —
 13,775
Issuance of common stock under incentive compensation plans, net of tax—
 3
 —
 —
 (3) —
 —
Equity-based compensation—
 8,713
 —
 —
 —
 661
 9,374
Purchase of treasury stock—
 —
 —
 —
 (73,225) —
 (73,225)
Purchase of HEP units for restricted grants—
 —
 —
 —
 —
 (373) (373)
Balance at March 31, 2019$2,560
 $4,204,841
 $4,393,108
 $27,398
 $(2,563,867) $530,534
 $6,594,574
Net income—
 —
 196,915
 —
 —
 19,902
 216,817
Dividends ($0.33 declared per common share)—
 —
 (56,659) —
 —
 —
 (56,659)
Distributions to noncontrolling interest holders—
 —
 —
 —
 —
 (33,030) (33,030)
Other comprehensive income, net of tax—
 —
 —
 2,804
 —
 —
 2,804
Equity attributable to HEP common unit issuances, net of tax—
 —
 —
 —
 —
 (140) (140)
Issuance of common stock under incentive compensation plans, net of tax—
 (138) —
 —
 138
 —
 —
Equity-based compensation—
 11,602
 —
 —
 —
 586
 12,188
Purchase of treasury stock—
 —
 —
 —
 (205,555) —
 (205,555)
Balance at June 30, 2019$2,560
 $4,216,305
 $4,533,364
 $30,202
 $(2,769,284) $517,852
 $6,530,999
Net income—
 —
 261,813
 —
 —
 36,167
 297,980
Dividends ($0.33 declared per common share)—
 —
 (54,500) —
 —
 —
 (54,500)
Distributions to noncontrolling interest holders—
 —
 —
 —
 —
 (33,392) (33,392)
Other comprehensive loss, net of tax—
 —
 —
 (12,985) —
 —
 (12,985)
Issuance of common stock under incentive compensation plans, net of tax—
 (80) —
 —
 80
 —
 —
Equity-based compensation—
 8,545
 —
 —
 —
 528
 9,073
Purchase of treasury stock—
 —
 —
 —
 (195,812) —
 (195,812)
Balance at September 30, 2019$2,560
 $4,224,770
 $4,740,677
 $17,217
 $(2,965,016) $521,155
 $6,541,363
 HollyFrontier Stockholders' Equity    
 Common Stock  Additional Capital Retained Earnings Accumulated Other Comprehensive Income (Loss) Treasury Stock Non-controlling Interest Total
Equity
  
Balance at December 31, 2019$2,560
 $4,204,547
 $4,744,120
 $14,774
 $(2,987,808) $531,233
 $6,509,426
Net income (loss)—
 —
 (304,623) —
 —
 11,337
 (293,286)
Dividends ($0.35 declared per common share)—
 —
 (57,248) —
 —
 —
 (57,248)
Distributions to noncontrolling interest holders—
 —
 —
 —
 —
 (33,918) (33,918)
Other comprehensive loss, net of tax—
 —
 —
 (26,923) —
 —
 (26,923)
Issuance of common stock under incentive compensation plans, net of forfeitures—
 (2,037) —
 —
 2,037
 —
 —
Equity-based compensation—
 5,824
 —
 —
 —
 506
 6,330
Purchase of treasury stock—
 —
 —
 —
 (1,062) —
 (1,062)
Purchase of HEP units for restricted grants—
 —
 —
 —
 —
 (145) (145)
Contributions from noncontrolling interests—
 —
 —
 —
 —
 7,304
 7,304
Balance at March 31, 2020$2,560
 $4,208,334
 $4,382,249
 $(12,149) $(2,986,833) $516,317
 $6,110,478
Net income (loss)—
 —
 (176,677) —
 —
 26,270
 (150,407)
Dividends ($0.35 declared per common share)—
 —
 (57,182) —
 —
 —
 (57,182)
Distributions to noncontrolling interest holders—
 —
 —
 —
 —
 (17,090) (17,090)
Other comprehensive income, net of tax—
 —
 —
 14,374
 —
 —
 14,374
Issuance of common stock under incentive compensation plans, net of forfeitures—
 (527) —
 —
 527
 —
 —
Equity-based compensation—
 7,484
 —
 —
 —
 475
 7,959
Purchase of treasury stock—
 —
 —
 —
 (181) —
 (181)
Purchase of HEP units for restricted grants—
 —
 —
 —
 —
 (2) (2)
Contributions from noncontrolling interests—
 —
 —
 —
 —
 5,959
 5,959
Reclamation of stockholder short-swing profit—
 603
 —
 —
 —
 —
 603
Balance at June 30, 2020$2,560
 $4,215,894
 $4,148,390
 $2,225
 $(2,986,487) $531,929
 $5,914,511




HollyFrontier Stockholders' Equity    HollyFrontier Stockholders' Equity    
Common Stock  Additional Capital Retained Earnings Accumulated Other Comprehensive Income Treasury stock Non-controlling Interest Total
Equity		Common Stock  Additional Capital Retained Earnings Accumulated Other Comprehensive Income Treasury Stock Non-controlling Interest Total
Equity
  
Balance at December 31, 2017$2,560
 $4,132,696
 $3,346,615
 $29,869
 $(2,140,911) $526,111
 $5,896,940
Balance at December 31, 2018$2,560
 $4,196,125
 $4,196,902
 $13,623
 $(2,490,639) $540,488
 $6,459,059
Net income—
 —
 268,091
 —
 —
 20,771
 288,862
—
 —
 253,055
 —
 —
 23,431
 276,486
Dividends ($0.33 declared per common share)—
 —
 (58,856) —
 —
 —
 (58,856)—
 —
 (56,849) —
 —
 —
 (56,849)
Distributions to noncontrolling interest holders—
 —
 —
 —
 —
 (29,237) (29,237)—
 —
 —
 —
 —
 (33,673) (33,673)
Other comprehensive loss, net of tax—
 —
 —
 (13,580) —
 —
 (13,580)
Equity attributable to HEP common unit issuances, net of tax—
 41,980
 —
 —
 —
 58,031
 100,011
Issuance of common stock under incentive compensation plans, net of tax—
 1,057
 —
 —
 (1,057) —
 —
Other comprehensive income, net of tax—
 —
 —
 13,775
 —
 —
 13,775
Issuance of common stock under incentive compensation plans, net of forfeitures—
 3
 —
 —
 (3) —
 —
Equity-based compensation—
 7,961
 —
 —
 —
 836
 8,797
—
 8,713
 —
 —
 —
 661
 9,374
Purchase of treasury stock—
 —
 —
 —
 (27,520) —
 (27,520)—
 —
 —
 —
 (73,225) —
 (73,225)
Purchase of HEP units for restricted grants—
 —
 —
 —
 —
 (58) (58)—
 —
 —
 —
 —
 (373) (373)
Adoption of accounting standards—
 —
 (11,019) 3,572
 —
 —
 (7,447)
Other—
 1
 (1) —
 —
 —
 —
Balance at March 31, 2018$2,560
 $4,183,695
 $3,544,830
 $19,861
 $(2,169,488) $576,454
 $6,157,912
Net income—
 —
 345,507
 —
 —
 17,406
 362,913
Dividends ($0.33 declared per common share)—
 —
 (58,644) —
 —
 —
 (58,644)
Distributions to noncontrolling interest holders—
 —
 —
 —
 —
 (31,522) (31,522)
Other comprehensive loss, net of tax—
 —
 —
 (7,948) —
 —
 (7,948)
Equity attributable to HEP common unit issuances, net of tax—
 221
 —
 —
 —
 232
 453
Issuance of common stock under incentive compensation plans, net of tax—
 335
 —
 —
 (335) —
 —
Equity-based compensation—
 7,797
 —
 —
 —
 712
 8,509
Purchase of treasury stock—
 —
 —
 —
 (28,030) —
 (28,030)
Other—
 (3) 3
 —
 —
 —
 —
Balance at June 30, 2018$2,560
 $4,192,045
 $3,831,696
 $11,913
 $(2,197,853) $563,282
 $6,403,643
Balance at March 31, 2019$2,560
 $4,204,841
 $4,393,108
 $27,398
 $(2,563,867) $530,534
 $6,594,574
Net income—
 —
 342,466
 —
 —
 19,666
 362,132
—
 —
 196,915
 —
 —
 19,902
 216,817
Dividends ($0.33 declared per common share)—
 —
 (58,421) —
 —
 —
 (58,421)—
 —
 (56,659) —
 —
 —
 (56,659)
Distributions to noncontrolling interest holders—
 —
 —
 —
 —
 (32,369) (32,369)—
 —
 —
 —
 —
 (33,030) (33,030)
Other comprehensive income, net of tax—
 —
 —
 10,883
 —
 —
 10,883
—
 —
 —
 2,804
 —
 —
 2,804
Equity attributable to HEP common unit issuances, net of tax—
 —
 —
 —
 —
 (61) (61)—
 —
 —
 —
 —
 (140) (140)
Issuance of common stock under incentive compensation plans, net of tax—
 (188) —
 —
 188
 —
 —
Issuance of common stock under incentive compensation plans, net of forfeitures—
 (138) —
 —
 138
 —
 —
Equity-based compensation—
 8,082
 —
 —
 —
 708
 8,790
—
 11,602
 —
 —
 —
 586
 12,188
Purchase of treasury stock—
 —
 —
 —
 (131,082) —
 (131,082)—
 —
 —
 —
 (205,555) —
 (205,555)
Adoption of accounting standards—
 —
 (3,110) 3,110
 —
 —
 —
Other—
 (1) (2) —
 —
 —
 (3)
Balance at September 30, 2018$2,560
 $4,199,938
 $4,112,629
 $25,906
 $(2,328,747) $551,226
 $6,563,512
Balance at June 30, 2019$2,560
 $4,216,305
 $4,533,364
 $30,202
 $(2,769,284) $517,852
 $6,530,999

See accompanying notes.

Table of Content

HOLLYFRONTIER CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)


NOTE 1:Description of Business and Presentation of Financial Statements

References herein to HollyFrontier Corporation (“HollyFrontier”) include HollyFrontier and its consolidated subsidiaries. In accordance with the Securities and Exchange Commission’s (“SEC”) “Plain English” guidelines, this Quarterly Report on Form 10-Q has been written in the first person. In these financial statements, the words “we,” “our,” “ours” and “us” refer only to HollyFrontier and its consolidated subsidiaries or to HollyFrontier or an individual subsidiary and not to any other person, with certain exceptions. Generally, the words “we,” “our,” “ours” and “us” include Holly Energy Partners, L.P. (“HEP”) and its subsidiaries as consolidated subsidiaries of HollyFrontier, unless when used in disclosures of transactions or obligations between HEP and HollyFrontier or its other subsidiaries. These financial statements contain certain disclosures of agreements that are specific to HEP and its consolidated subsidiaries and do not necessarily represent obligations of HollyFrontier. When used in descriptions of agreements and transactions, “HEP” refers to HEP and its consolidated subsidiaries.

We are an independent petroleum refiner and marketer that produces high-value light products such as gasoline, diesel fuel, jet fuel and other specialty products. We own and operate petroleum refineries that serve markets throughout the Mid-Continent, Southwest and Rocky Mountain regions of the United States. In addition, we produce base oils and other specialized lubricants in the United States, Canada and the Netherlands, with retail and wholesale marketing of our products through a global sales network with locations in Canada, the United States, Europe, China and Latin America.

As of SeptemberJune 30, 20192020, we:

•
owned and operated a petroleum refinery in El Dorado, Kansas (the “El Dorado Refinery”), 2 refinery facilities located in Tulsa, Oklahoma (collectively, the “Tulsa Refineries”), a refinery in Artesia, New Mexico that is operated in conjunction with crude oil distillation and vacuum distillation and other facilities situated 65 miles away in Lovington, New Mexico (collectively, the “Navajo Refinery”), a refinery located in Cheyenne, Wyoming (the “Cheyenne Refinery”) and a refinery in Woods Cross, Utah (the “Woods Cross Refinery”);
owned and operated Petro-Canada Lubricants Inc. (“PCLI”) located in Mississauga, Ontario, which produces base oils and other specialized lubricant products;
owned and operated Sonneborn (as defined below) with manufacturing facilities in Petrolia, Pennsylvania and the Netherlands;Netherlands, which produce specialty lubricant products, such as white oils, petrolatums and waxes;
owned and operated Red Giant Oil Company LLC (“Red Giant Oil”), which supplies locomotive engine oil withand has storage and distribution facilities in Iowa, Kansas, Utah and Wyoming, along with a blending and packaging facility in Texas;
owned and operated HollyFrontier Asphalt Company LLC (“HFC Asphalt”), which operates various asphalt terminals in Arizona, New Mexico and Oklahoma; and
owned a 57% limited partner interest and a non-economic general partner interest in HEP, a variable interest entity (“VIE”). HEP owns and operates logistic assets consisting of petroleum product and crude oil pipelines, terminals, tankage, loading rack facilities and refinery processing units that principally support our refining and marketing operations in the Mid-Continent, Southwest and Rocky Mountain regions of the United States.

On June 1, 2020, we announced plans to permanently cease petroleum refining operations at our Cheyenne Refinery and to convert certain assets at our Cheyenne Refinery to renewable diesel production. We subsequently began winding down refining operations at our Cheyenne Refinery on August 3, 2020. This decision was primarily based on a positive outlook on the market for renewable diesel and the expectation that future free cash flow generation at our Cheyenne Refinery would be challenged due to lower gross margins resulting from the economic impact of the COVID-19 pandemic and compressed crude differentials due to dislocations in the crude oil market. Additional factors included uncompetitive operating and maintenance costs forecasted for our Cheyenne Refinery and the anticipated loss of the Environmental Protection Agency’s (“EPA”) small refinery exemption. Approximately 200 employees at our Cheyenne Refinery are expected to be impacted by this decision.


During the second quarter of 2020, we recorded a long-lived asset impairment of $232.2 million and accelerated depreciation of $2.2 million related to our Cheyenne Refinery asset groups. We expect to record additional non-cash charges of $3.7 million for accelerated depreciation in the third quarter of 2020. Additionally, during the second quarter of 2020, we recorded $1.1 million in employee severance costs related to the conversion of our Cheyenne Refinery. Also, during the second quarter of 2020, we recorded a reserve of $6.2 million against our repair and maintenance supplies inventory. These severance costs and the inventory reserve charge were recognized in operating expenses and were reported in our Refining segment.

During the second quarter of 2020, we initiated and completed a corporate restructuring. As a result of this restructuring, we recorded $3.7 million in employee severance costs, which were recognized primarily as operating expenses in our Refining segment and selling, general and administrative expenses in our Corporate and Other segment.

On November 12, 2018, we entered into an equity purchase agreement to acquire 100% of the issued and outstanding capital stock of Sonneborn US Holdings Inc. and 100% of the membership rights in Sonneborn Coöperatief U.A. (collectively, “Sonneborn”). The acquisition closed on February 1, 2019. Aggregate consideration totaled $701.6 million and consisted of $662.7 million in cash paid at acquisition, net of cash acquired. Sonneborn is a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes with manufacturing facilities in the United States and Europe.

On July 10, 2018, we entered intoThis transaction was accounted for as a definitive agreementbusiness combination using the acquisition method of accounting, with the purchase price allocated to acquire Red Giant Oil, a privately-owned lubricants company. Thethe fair value of the acquired Sonneborn assets and liabilities as of the February 1, 2019 acquisition closed on August 1, 2018.date, with the excess purchase price recorded as goodwill assigned to our Lubricants and Specialty Products segment. This goodwill is not deductible for income tax purposes. Fair values are as follows: cash and cash equivalents $38.9 million, current assets $139.4 million, properties, plants and equipment $168.2 million, goodwill $282.3 million, intangibles and other noncurrent assets $231.5 million, current liabilities $47.9 million and deferred income tax and other long-term liabilities $110.8 million.

We incurred $0.6 million and $3.6 million for the three months ended June 30, 2020 and 2019, respectively, and $1.9 million and $16.2 million for the six months ended June 30, 2020 and 2019, respectively, in incremental direct integration and regulatory costs that principally relate to legal, advisory and other professional fees and are presented as selling, general and administrative expenses.

We have prepared these consolidated financial statements without audit. In management’s opinion, these consolidated financial statements include all normal recurring adjustments necessary for a fair presentation of our consolidated financial position as of SeptemberJune 30, 20192020, the consolidated results of operations, comprehensive income and statements of equity for the three and ninesix months ended SeptemberJune 30, 20192020 and 20182019 and consolidated cash flows for the ninesix months ended SeptemberJune 30, 20192020 and 20182019 in accordance with the rules and regulations of the SEC. Although certain notes and other information required by generally accepted accounting principles in the United States (“GAAP”) have been condensed or omitted, we believe that the disclosures in these consolidated financial statements are adequate to make the information presented not misleading. These consolidated financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 20182019 that has been filed with the SEC.


Our results of operations for the ninesix months ended SeptemberJune 30, 20192020 are not necessarily indicative of the results of operations to be realized for the year ending December 31, 20192020.

Accounts Receivable: Our accounts receivable consist of amounts due from customers that are primarily companies in the petroleum industry. Credit is extended based on our evaluation of the customer’s financial condition, and in certain circumstances collateral, such as letters of credit or guarantees, is required. We reserve for doubtful accounts based on our historical loss experience as well as specific accounts identified as high risk, which historically have been minimal.expected credit losses from current economic conditions and management’s expectations of future economic conditions. Credit losses are charged to the allowance for doubtful accounts when an account is deemed uncollectible. Our allowance for doubtful accounts was $4.4$3.4 million at SeptemberJune 30, 20192020 and $3.6$4.5 million at December 31, 20182019.


Inventories: Inventories related to our refining operations are stated at the lower of cost, using the last-in, first-out (“LIFO”) method for crude oil and unfinished and finished refined products, or market. In periods of rapidly declining prices, LIFO inventories may have to be written down to market value due to the higher costs assigned to LIFO layers in prior periods. In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. An actual valuation of inventory under the LIFO method is made at the end of each year based on the inventory levels at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and are subject to the final year-end LIFO inventory valuation.

Inventories of our Petro-Canada Lubricants and Sonneborn businesses are stated at the lower of cost, using the first-in, first-out (“FIFO”) method, or net realizable value.

Inventories consisting of process chemicals, materials and maintenance supplies and renewable identification numbers (“RINs”) are stated at the lower of weighted-average cost or net realizable value.

Leases: At inception, we determine if an arrangement is or contains a lease. Right-of-use (“ROU”) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our payment obligation under the leasing arrangement. ROU assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. We use our estimated incremental borrowing rate (“IBR”) to determine the present value of lease payments as most of our leases do not contain an implicit rate. Our IBR represents the interest rate which we would pay to borrow, on a collateralized basis, an amount equal to the lease payments over a similar term in a similar economic environment. We use the implicit rate when readily determinable.

Operating leases are recorded in operating lease right-of-use assets and current and noncurrent operating lease liabilities on our consolidated balance sheet. Finance leases are included in properties, plants and equipment and accrued liabilities and other long-term liabilities on our consolidated balance sheet.

Our lease term includes an option to extend the lease when it is reasonably certain that we will exercise that option. Leases with a term of 12 months or less are not recorded on our balance sheet and lease expense is accounted for on a straight-line basis.sheet. For certain equipment leases, we apply a portfolio approach for the operating lease ROU assets and liabilities. Also, as a lessee, we separate non-lease components that are identifiable and exclude them from the determination of net present value of lease payment obligations. In addition, HEP, as a lessor, does not separate the non-lease (service) component in contracts in which the lease component is the dominant component. HEP treats these combined components as an operating lease.


Goodwill and Long-lived Assets: As of SeptemberJune 30, 2019,2020, our goodwill balance was $2.4 billion, with goodwill assigned to our Refining, Lubricants and Specialty Products and HEP segments of $1,733.5 million, $324.1$327.6 million and $312.9 million, respectively. During the nine months ended September 30, 2019, we recognized $279.2 million in goodwill as a result of our Sonneborn acquisition, all of which has been assigned to our Lubricants and Specialty Products segment. See Note 1715 for additional information on our segments. The carrying amount of our goodwill may fluctuate from period to period due to the effects of foreign currency translation adjustments on goodwill assigned to our Lubricants and Specialty Products segment. Goodwill represents the excess of the cost of an acquired entity over the fair value of the assets acquired and liabilities assumed. Goodwill is not subject to amortization and is tested annually or more frequently 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. Our goodwill impairment testing first entails either a quantitative assessment or an optional qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If we determine that based on the qualitative factors that it is more likely than not that the fair value of the reporting unit is greater than its carrying amount, a quantitative test is performed in which we estimate the fair value of the related reporting unit. If the carrying amount of a reporting unit exceeds its fair value, the goodwill of that reporting unit is impaired, and we measure goodwill impairment as the excess of the carrying amount of the reporting unit over the related fair value.

OurFor purposes of long-lived asset impairment evaluation, we have grouped our long-lived assets principally consist ofas follows: (i) our refining assets that are organized as refiningrefinery asset groups, and thewhich include certain HEP logistics assets, of(ii) our Lubricants and Specialty Products asset groups. Thegroups and (iii) our HEP asset groups, which comprises HEP assets not included in our refinery asset groups. These asset groups also constitute our individual refinery reporting units that are usedrepresent the lowest level for testing and measuring goodwill impairments.which independent cash flows can be identified. Our long-lived assets are evaluated for impairment by identifying whether indicators of impairment exist and if so, assessing whether the long-lived assets are recoverable from estimated future undiscounted cash flows. The actual amount of impairment loss measured, if any, is equal to the amount by which the asset group’s carrying value exceeds its fair value.

Goodwill
Indicators of goodwill and long-lived asset impairment
Due to the recent economic slowdown caused by the COVID-19 pandemic, we determined that indicators of potential goodwill impairment for our Refining and Lubricants and Specialty Products reporting units were present. In addition, we determined that these indicators were also evidence of potential long-lived asset impairments. These indicators included reductions in the prices of our finished goods and raw materials and the related decrease in our gross margins, as well as the recent decline in our common share price which has resulted in a decrease in our market capitalization. Additionally, our recent announcement of the conversion of our Cheyenne Refinery to renewable diesel production was also considered a triggering event requiring assessment of potential impairments to the carrying value of our Cheyenne Refinery asset group. During the second quarter of 2019,2020, we performed interim goodwill and long-lived asset impairment testing of the PCLI reporting unit included in our Lubricants and Specialty Products segment. We elected to perform this interim assessment due to the recent reorganization of our reporting unit structure within the Lubricants and Specialty Products segment, combined with the identification of events and circumstances which were indicators of potential goodwill impairment at PCLI, including recent declines in gross margins to lower than historic levels. These recent lower gross margins are in the base oil market which is largely attributed to the increase in global supply of base oils with a current outlook for continued near-term softness.

Our interim goodwill impairment testing was performed as of May 31, 2019. 2020.

Long-lived asset impairment testing
As a result of our long-lived asset impairment testing, we determined that the carrying value of the long-lived assets of our Cheyenne Refinery and PCLI asset groups were not recoverable, and thus recorded long-lived asset impairment charges of $232.2 million and $204.7 million, respectively, in the second quarter of 2020. Our testing did not result in any other impairment of long-lived assets.

The estimated fair values of the Cheyenne Refinery and PCLI asset groups were determined using a combination of the income and cost approaches. The income approach was based on management’s best estimates of the expected future cash flows over the remaining useful life of the asset group. The cost approach utilized assumptions for the current replacement costs of similar assets adjusted for estimated depreciation and economic obsolescence. These fair value measurements involve significant unobservable inputs (Level 3 inputs). See Note 4 for further discussion of Level 3 inputs.

Goodwill impairment testing
The estimated fair values of our goodwill reporting units within ourRefining and Lubricants and Specialty Products segmentreporting units were derived using a combination of both income and market approaches. The income approach reflects expected future cash flows based on estimated futureforecasted production volumes,levels, selling prices, gross margins, operating costs and capital expenditures. Our market approach includesapproaches include both the guideline public company and guideline transaction methods. Both methods utilize pricing multiples derived from historical market transactions of other like-kind assets. These fair value measurements involve significant unobservable inputs (Level 3 inputs). See Note 64 for further discussion of Level 3 inputs.

As a resultOur interim goodwill impairment testing indicated that the fair values of our impairment testing, we determined that the carrying value of the PCLI reporting unit’s goodwill within ourRefining and Lubricants and Specialty Products segmentreporting units were in excess of their respective carrying amounts ranging from 9% to 283%; therefore, there was fully impairedno impairment of goodwill at our Refining and Lubricants and Specialty Products reporting units.

A reasonable expectation exists that further deterioration in our operating results or overall economic conditions could result in an impairment of goodwill and / or additional long-lived assets impairments at some point in the future. Future impairment charges could be material to our results of operations and financial condition. Our annual goodwill impairment testing is performed on July 1.

During the second quarter of 2019, we recorded a goodwill impairment charge of $152.7 million was recorded. Our testing did not identify any other impairments.

We performedto fully impair the goodwill of the PCLI reporting unit included in our annual goodwill impairment testing as of July 1, 2019Lubricants and determined there was no additional impairment of goodwill attributable to our reporting units.Specialty Products segment.

Revenue Recognition: Revenue on refined product and excess crude oil sales are recognized when delivered (via pipeline, in-tank or rack) and the customer obtains control of such inventory, which is typically when title passes and the customer is billed. All revenues are reported inclusive of shipping and handling costs billed and exclusive of any taxes billed to customers. Shipping and handling costs incurred are reported as cost of products sold. Additionally, our

Our lubricants and specialty products business has sales agreements with marketers and distributors that provide certain rights of return or provisions for the repurchase of products previously sold to them. Under these agreements, revenues and cost of revenues are deferred until the products have been sold to end customers. Our lubricants and specialty products business also has agreements that create an obligation to deliver products at a future date for which consideration has already been received and recorded as deferred revenue. This revenue is recognized when the products are delivered to the customer.



HEP recognizes revenues as products are shipped through its pipelines and terminals and as other services are rendered. Additionally, HEP has certain throughput agreements that specify minimum volume requirements, whereby HEP bills a customer for a minimum level of shipments in the event a customer ships below their contractual requirements. If there are no future performance obligations, HEP recognizes these deficiency payments as revenue. In certain of these throughput agreements, a customer may later utilize such shortfall billings as credit towards future volume shipments in excess of its minimum levels within its respective contractual shortfall make-up period. Such amounts represent an obligation to perform future services, which may be initially deferred and later recognized as revenue based on estimated future shipping levels, including the likelihood of a customer’s ability to utilize such amounts prior to the end of the contractual shortfall make-up period. HEP recognizes the service portion of these deficiency payments as revenue when HEP does not expect it will be required to satisfy these performance obligations in the future based on the pattern of rights exercised by the customer. Payment terms under our contracts with customers are consistent with industry norms and are typically payable within 30 days of the date of invoice.

Foreign Currency Translation: Assets and liabilities recorded in foreign currencies are translated into U.S. dollars using exchange rates in effect as of the balance sheet date. Revenue and expense accounts are translated using the weighted-average exchange rates during the period presented. Foreign currency translation adjustments are recorded as a component of accumulated other comprehensive income.

In connection with our PCLI acquisition, on February 1, 2017, we issued intercompany notes to initially fund certain of our foreign businesses. Remeasurement adjustments resulting from the conversion of such intercompany financing amounts to functional currencies are recorded as gains and losses as a component of other income (expense) in the income statement. Such adjustments are not recorded to the Lubricants and Specialty Products segment operations, but to Corporate and Other. See Note 1715 for additional information on our segments.

Income Taxes: Provisions for income taxes include deferred taxes resulting from temporary differences in income for financial and tax purposes, using the liability method of accounting for income taxes. The liability method requires the effect of tax rate changes on deferred income taxes to be reflected in the period in which the rate change was enacted. The liability method also requires that deferred tax assets be reduced by a valuation allowance unless it is more likely than not that the assets will be realized.

Potential interest and penalties related to income tax matters are recognized in income tax expense. We believe we have appropriate support for the income tax positions taken and to be taken on our income tax returns and that our accruals for tax liabilities are adequate for all open years based on an assessment of many factors, including past experience and interpretations of tax law applied to the facts of each matter.

For the six months ended June 30, 2020, we recorded an income tax benefit of $193.1 million compared to income tax expense of $176.8 million for the six months ended June 30, 2019. This decrease was due principally to a pre-tax loss during the six months ended June 30, 2020 compared to pre-tax earnings in the same period of 2019. Our effective tax rates were 30.3% and 26.4% for the six months ended June 30, 2020 and 2019, respectively. The year-over-year increase in the effective tax rate is due principally to the relationship between the pre-tax results and the earnings attributable to the noncontrolling interest that is not included in income for tax purposes.

Inventory Repurchase Obligations: We periodically enter into same-party sell / buy transactions, whereby we sell certain refined product inventory and subsequently repurchase the inventory in order to facilitate delivery to certain locations. Such sell / buy transactions are accounted for as inventory repurchase obligations under which proceeds received under the initial sell is recognized as an inventory repurchase obligation that is subsequently reversed when the inventory is repurchased. For the ninesix months ended SeptemberJune 30, 20192020 and 2018,2019, we received proceeds of $13.2$20.4 million and $38.4$12.6 million, respectively, and subsequently repaid $12.5$21.7 million and $39.3$12.9 million, respectively, under these sell / buy transactions.

Accounting Pronouncements - Recently Adopted

Goodwill Impairment TestingIncome Tax Accounting
In January 2017,December 2019, Accounting StandardStandards Update (“ASU”) 2017-04,2019-12, “Simplifying the TestAccounting for Goodwill Impairment,Income Taxes,” was issued amending the testing for goodwill impairment by eliminating Step 2 from the goodwill impairment test. Step 2 measures a goodwill impairment loss by comparing the implied fair value of a reporting unit’s goodwill with the carrying amount of that goodwill. We adopted this standard effective in the second quarter of 2019, and the adoption of this standard resulted in no changewhich eliminates some exceptions to the amountgeneral approach in ASC Topic 740 “Income Taxes” and also provides clarification of goodwill impairment recorded in the second quarterother aspects of 2019.


Leases
In February 2016, ASU 2016-02, “Leases,” was issued requiring leases to be measured and recognized as a lease liability, with a corresponding ROU asset on the balance sheet.ASC 740. We adopted this standard effective January 1, 2019 using2020 on a prospective basis, and recognized an income tax benefit for the optional transition method, whereby comparative prior period financial information will not be restated and will continuesix months ended June 30, 2020 based upon the application of our estimated annual effective tax rate to be reported under the lease accounting standard in effect during those periods. We also elected practical expedients provided by the new standard, including the package of practical expedients, whereby we did not reassess lease classification or initial indirect lease cost under the new standard. In addition, we elected to exclude short-term leases, which at inception have a lease term of 12 months or less, from the amounts recognized on our balance sheet. In addition, HEP elected an expedient whereby a lessor does not have to separate non-lease (service) components from lease components under certain contracts. Under this expedient, HEP treated the combined components of its leases with third parties (i.e., the contracts that are not eliminated upon consolidation of HEP by HFC) as an operating lease in which the dominant component was a lease in accordance with ASC 842. Upon adoption of this standard, we recognized $433.4 million of lease liabilities and corresponding ROU assets on our consolidated balance sheet. Adoption of this standard did not have a material impact on our results of operations or cash flows. In addition, upon our acquisition of Sonneborn on February 1, 2019, we recognized $15.6 million of lease liabilities and corresponding ROU assets.pre-tax loss.

Accounting Pronouncements - Not Yet Adopted


Credit Losses Measurement
In June 2016, ASU 2016-13, “Measurement of Credit Losses on Financial Instruments,” was issued requiring measurement of all expected credit losses for certain types of financial instruments, including trade receivables, held at the reporting date based on historical experience, current conditions and reasonable and supportable forecasts. ThisWe adopted this standard is effective January 1, 2020, andat which time our preliminary review of historic and expected credit losses indicatesresulted in a decrease of $3.2 million in our reserve for doubtful accounts. Based upon our assessment of the amountpotential impact of current and forecasted conditions, we increased our reserve for doubtful accounts by $2.1 million during the six months ended June 30, 2020. Assumptions about the potential effects of the COVID-19 pandemic on our estimate of expected credit losses upon adoption would not be materially different from theare inherently subjective and difficult to forecast. However, we believe that our current estimate of allowance for doubtful accounts balance.to be reasonable based upon current information and forecasts.


NOTE 2:Acquisitions

On November 12, 2018, we entered into an equity purchase agreement to acquire100% of the capital stock of Sonneborn. The acquisition closed on February 1, 2019. Sonneborn is a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes with manufacturing facilities in the United States and Europe.

Aggregate consideration totaled $701.6 million and consisted of $662.7 million in cash paid at acquisition, net of cash acquired. Working capital settlement pursuant to the purchase agreement has been finalized.

This transaction is accounted for as a business combination using the acquisition method of accounting, with the purchase price allocated to the fair value of the acquired Sonneborn assets and liabilities as of the February 1 acquisition date, with the excess purchase price recorded as goodwill assigned to our Lubricants and Specialty Products segment.

The following summarizes our preliminary value estimates of the Sonneborn assets and liabilities acquired on February 1, 2019:
 (In millions)
Cash and cash equivalents$38.9
Accounts receivable and other current assets58.6
Inventories81.0
Properties, plants and equipment168.2
Goodwill279.2
Intangibles and other noncurrent assets231.5
Accounts payable and accrued liabilities(47.0)
Deferred income tax liabilities(84.5)
Other long-term liabilities(24.3)
 $701.6



The preliminary purchase price allocation resulted in the recognition of $279.2 million in goodwill, which relates to the established workforce and global market presence of the acquired business as well as the expected synergies to be gained upon combining with our existing operations to form an expanded lubricants and specialty products business.

Intangibles include customer relationships, trademarks, patents and technical know-how totaling $214.6 million that are being amortized on a straight-line basis over a 12-year period.

These values, including deferred taxes, are preliminary and, therefore, may change once we complete our valuations.

Our consolidated financial and operating results reflect the Sonneborn operations beginning February 1, 2019. Our results of operations for the three months ended September 30, 2019 included revenues and income before income taxes of $88.1 million and $6.6 million, respectively, and revenue and income before income taxes of $253.5 million and $5.0 million, respectively, for the period from February 1, 2019 through September 30, 2019 related to these operations.

As of September 30, 2019, we have incurred $20.1 million in incremental direct integration and regulatory costs that principally relate to legal, advisory, regulatory and other professional fees and are presented as selling, general and administrative expenses.

The following unaudited pro forma information for the nine months ended September 30, 2019 and the three and nine months ended September 30, 2018 presents the revenues and operating income for our Lubricants and Specialty Products segment assuming the acquisition of Sonneborn had occurred as of January 1, 2018. The proforma effects on consolidated HFC revenue and operating income are not material.
  Three Months Ended
September 30,		 Nine Months Ended
September 30,
  2018 2019 2018
  (In thousands)
Sales and other revenues $571,685
 $1,608,648
 $1,679,554
Operating income (1)
 $39,496
 $(127,972) $110,424


(1) For the nine months ended September 30, 2019, includes goodwill impairment of $152.7 million from the PCLI reporting unit of our Lubricants and Specialty Products segment. See Note 1 for additional information on this goodwill impairment.


NOTE 3:Leases

We have operating and finance leases for land, buildings, pipelines, storage tanks, transportation and other equipment for our operations. Our leases have remaining terms of one to 60 years, some of which include options to extend the leases for up to 10 years. Certain of our leases for pipeline assets include provisions for variable payments which are based on a measure of throughput and also contain a provision for the lessor to adjust the rate per barrel periodically over the life of the lease. These variable costs are not included in the initial measurement of ROU assets and lease liabilities.


The following table presents the amounts and balance sheet locations of our operating and financing leases recorded on our consolidated balance sheet.
  September 30, 2019
  (In thousands)
Operating leases:  
Operating lease right-of-use assets $453,377
   
Operating lease liabilities 99,622
Noncurrent operating lease liabilities 355,410
Total operating lease liabilities $455,032
   
Finance leases:  
Properties, plants and equipment, at cost $12,830
Accumulated amortization (6,375)
Properties, plants and equipment, net $6,455
   
Accrued liabilities $1,663
Other long-term liabilities 4,929
Total finance lease liabilities $6,592

Supplemental balance sheet information related to our leases was as follows:
September 30, 2019
Weighted average remaining lease term (in years)
Operating leases7.6
Finance leases8.2
Weighted average discount rate
Operating leases4.2%
Finance leases5.3%


The components of lease expense were as follows:
  Three Months Ended
September 30, 2019		 Nine Months Ended
September 30, 2019
  (In thousands)
Operating lease expense $28,263
 $83,646
Finance lease expense:    
Amortization of right-of-use assets 375
 1,150
Interest on lease liabilities 84
 255
Variable lease cost 1,862
 3,251
Total lease expense $30,584
 $88,302

Supplemental cash flow information related to leases was as follows:
  Nine Months Ended
September 30, 2019
  (In thousands)
Cash paid for amounts included in the measurement of lease liabilities:  
Operating cash flows from operating leases $88,500
Operating cash flows from finance leases $255
Financing cash flows from finance leases $1,158
   
Right-of-use assets obtained in exchange for lease obligations:  
Operating leases $80,211




As of September 30, 2019, minimum future lease payments of our operating and finance lease obligations were as follows:
  Operating Finance
  (In thousands)
Remainder of 2019 $29,036
 $500
2020 107,362
 1,945
2021 89,194
 1,123
2022 75,923
 859
2023 70,194
 895
2024 and thereafter 172,200
 2,772
Future minimum lease payments 543,909
 8,094
Less: imputed interest 88,877
 1,502
Total lease obligations 455,032
 6,592
Less: current obligations 99,622
 1,663
Long-term lease obligations $355,410
 $4,929


As of September 30, 2019, we have entered into certain leases that have not yet commenced. Such leases include a 15-year lease for plant equipment, with estimated future lease payments of $6.8 million, expected to commence in the second quarter of 2020, and a 5-year lease for office equipment, with estimated future lease payments of $0.4 million, expected to commence in the fourth quarter of 2019.

Our consolidated income statement reflects lease revenue recognized by HEP for contracts with third parties in which HEP is the lessor. Lease income recognized was as follows:

  Three Months Ended
September 30, 2019		 Nine Months Ended
September 30, 2019
  (In thousands)
Operating lease revenues $8,374
 $24,840


Annual minimum undiscounted lease payments in which HEP is a lessor to third-party contracts as of September 30, 2019 were as follows:

 (In thousands)
Remainder of 2019$8,010
202017,542
202112,794
202211,376
202311,248
Thereafter14,060
Total$75,030




NOTE 4:2:Holly Energy Partners

HEP is a publicly held master limited partnership that owns and operates logistic assets consisting of petroleum product and crude oil pipelines, terminals, tankage, loading rack facilities and refinery processing units that principally support our refining and marketing operations, as well as other third-party refineries, in the Mid-Continent, Southwest and Rocky Mountain regions of the United States and Delek’s refinery in Big Spring, Texas.States. Additionally, as of SeptemberJune 30, 2019,2020, HEP owned a 75% interest in UNEV Pipeline, LLC (“UNEV”), the owner of a pipeline running from Woods Cross, Utah to Las Vegas, Nevada (the “UNEV Pipeline”) and associated product terminals, and had a 50% ownership interest in each of Osage Pipe Line Company, LLC, the owner of a pipeline running from Cushing, Oklahoma to El Dorado, Kansas (the “Osage Pipeline”) and; Cheyenne Pipeline, LLC, the owner of a pipeline running from Fort Laramie, Wyoming to Cheyenne, Wyoming (the “Cheyenne Pipeline”). and Cushing Connect Pipeline & Terminal LLC (“Cushing Connect”), the owner of a crude oil storage terminal in Cushing, Oklahoma and a to-be-constructed pipeline that will run from Cushing, Oklahoma to our Tulsa Refineries.

As ofAt SeptemberJune 30, 20192020, we owned a 57% limited partner interest and a non-economic general partner interest in HEP. As the general partner of HEP, we have the sole ability to direct the activities that most significantly impact HEP’s financial performance, and therefore as HEP's primary beneficiary, we consolidate HEP.

HEP has 2 primary customers (including us) and generates revenues by charging tariffs for transporting petroleum products and crude oil through its pipelines, by charging fees for terminalling refined products and other hydrocarbons, and by storing and providing other services at its storage tanks and terminals. Under our long-term transportation agreements with HEP (discussed further below), we accounted for 78%81% of HEP’s total revenues for the ninesix months ended SeptemberJune 30, 20192020. We do not provide financial or equity support through any liquidity arrangements and / or debt guarantees to HEP.

HEP has outstanding debt under a senior secured revolving credit agreement and its senior notes. HEP’s creditors have no recourse to our assets. Furthermore, our creditors have no recourse to the assets of HEP and its consolidated subsidiaries. See Note 119 for a description of HEP’s debt obligations.

HEP has risk associated with its operations. If a major customer of HEP were to terminate its contracts or fail to meet desired shipping or throughput levels for an extended period of time, revenue would be reduced and HEP could suffer substantial losses to the extent that a new customer is not found. In the event that HEP incurs a loss, our operating results will reflect HEP’s loss, net of intercompany eliminations, to the extent of our ownership interest in HEP at that point in time.

HEP Private Placement Agreements
On January 25, 2018, HEP entered into a common unit purchase agreement in which certain purchasers agreed to purchase in a private placement 3,700,000 HEP common units, representing limited partner interests, at a price of $29.73 per common unit. The private placement closed on February 6, 2018, at which time HEP received proceeds of $110.0 million, which were used to repay indebtedness under the HEP Credit Agreement.

HEP Common Unit Continuous Offering Program
In May 2016, HEP established a continuous offering program under which HEP may issue and sell common units from time to time, representing limited partner interests, up to an aggregate gross sales amount of $200 million. During the nine months ended September 30, 2019, HEP did not issue any common units under this program. As of September 30, 2019, HEP has issued 2,413,153 common units under this program, providing $82.3 million in gross proceeds.

HEP intends to use the net proceeds for general partnership purposes, which may include funding working capital, repayment of debt, acquisitions and capital expenditures. Amounts repaid under HEP’s credit facility may be reborrowed from time to time.

As a result of these transactions and resulting HEP ownership changes, we adjusted additional capital and equity attributable to HEP's noncontrolling interest holders to reallocate HEP's equity among its unitholders.

Cushing Connect Joint Venture
OnIn October 2, 2019, HEP Cushing LLC (“HEP Cushing”), a wholly-owned subsidiary of HEP, and Plains Marketing, L.P. (“PMLP”), a wholly-owned subsidiary of Plains All American Pipeline, L.P. (“Plains”), formed a 50/50 joint venture, Cushing Connect, Pipeline & Terminal LLC (the “Joint Venture”), for (i) the development and construction of a new 160,000 barrel per day common carrier crude oil pipeline (the “Pipeline”“Cushing Connect Pipeline”) that will connect the Cushing, Oklahoma crude oil hub to our Tulsa Refineries and (ii) the ownership and operation of 1.5 million barrels of crude oil storage in Cushing, Oklahoma (the “JV“Cushing Connect Terminal”). The JVCushing Connect Terminal was fully in service beginning in April 2020, and the Cushing Connect Pipeline is expected to be in service during the second quarter of 2020, and the Pipeline is expected to beplaced in service during the first quarter of 2021. Long-term commercial agreements have been entered into to support the Joint VentureCushing Connect assets.



The Joint VentureCushing Connect will contract with an affiliate of HEP to manage the construction and operation of the Cushing Connect Pipeline and with an affiliate of Plains to manage the operation of the JVCushing Connect Terminal. The total Joint Venture investment in Cushing Connect will be shared proportionately among the partners, and HEP estimates its share of the cost of the JVCushing Connect Terminal contributed by Plains and Cushing Connect Pipeline construction costs are approximately $65.0 million.

Cushing Connect and its two subsidiaries, Cushing Connect Pipeline and Cushing Connect Terminal, are each VIE’s because they do not have sufficient equity at risk to finance their activities without additional financial support. HEP is the primary beneficiary of two of these entities as HEP is constructing and will operate the Cushing Connect Pipeline, and HEP has more ability to direct the activities that most significantly impact the financial performance of Cushing Connect and Cushing Connect Pipeline. Therefore, HEP consolidates these two entities. HEP is not the primary beneficiary of Cushing Connect Terminal, which HEP accounts for using the equity method of accounting.

Transportation Agreements
HEP serves our refineries under long-term pipeline, terminal and tankage throughput agreements and refinery processing tolling agreements expiring from 2021 through 2036. Under these agreements, we pay HEP fees to transport, store and process throughput volumes of refined products, crude oil and feedstocks on HEP’s pipeline, terminals, tankage, loading rack facilities and refinery processing units that result in minimum annual payments to HEP including UNEV (a consolidated subsidiary of HEP). Under these agreements, the agreed upon tariff rates are subject to annual tariff rate adjustments on July 1 at a rate based upon the percentage change in Producer Price Index or Federal Energy Regulatory Commission index. As of September 30, 2019,July 1, 2020, these agreements result in minimum annualized payments to HEP of $349.0$351.1 million.

Our transactions with HEP and fees paid under our transportation agreements with HEP and UNEV are eliminated and have no impact on our consolidated financial statements.

Lessor Accounting
Our consolidated statements of income reflect lease revenue recognized by HEP for contracts with third parties in which HEP is the lessor.

One of HEP’s throughput agreements with Delek US Holdings, Inc. (“Delek”) was renewed during the three months ended June 30, 2020. Certain components of this agreement met the criteria of sales-type leases since the underlying assets are not expected to have an alternative use at the end of the lease term to anyone other than Delek. Under sales-type lease accounting, at the commencement date, the lessor recognizes a net investment in the lease, based on the estimated fair value of the underlying leased assets at contract inception, and derecognizes the underlying assets with the difference recorded as selling profit or loss arising from the lease. Therefore, HEP recognized a gain on sales-type leases totaling $33.8 million, during the three months ended June 30, 2020. This sales-type lease transaction, including the related gain, was a non-cash transaction.

Lease income recognized was as follows:
  Three Months Ended
June 30,		 Six Months Ended
June 30,
  2020 2019 2020 2019
  (In thousands)
Operating lease revenues $5,442
 $8,267
 $13,732
 $16,466
Gain on sales-type leases $33,834
 $—
 $33,834
 $—
Sales-type lease interest income $642
 $—
 $642
 $—
Lease revenues relating to variable lease payments not included in measurement of the sales-type lease receivable $286
 $—
 $286
 $—

HEP Common Unit Continuous Offering Program
In May 2016, HEP established a continuous offering program under which HEP may issue and sell common units from time to time, representing limited partner interests, up to an aggregate gross sales amount of $200 million. During the six months ended June 30, 2020, HEP did not issue any common units under this program. As of June 30, 2020, HEP has issued 2,413,153 common units under this program, providing $82.3 million in gross proceeds.



NOTE 5:3:Revenues

Substantially all revenue-generating activities relate to sales of refined product and excess crude oil inventories sold at market prices (variable consideration) under contracts with customers. Additionally, we have revenues attributable to HEP logistics services provided under petroleum product and crude oil pipeline transportation, processing, storage and terminalling agreements with third parties.

Disaggregated revenues were as follows:    
  Three Months Ended
September 30,		 Nine Months Ended
September 30,
  2019 2018 2019 2018
  (In thousands)
Revenues by type        
Refined product revenues        
Transportation fuels (1)
 $3,354,927
 $3,598,815
 $9,796,334
 $10,193,218
Specialty lubricant products (2)
 461,669
 422,760
 1,413,194
 1,237,002
Asphalt, fuel oil and other products (3)
 299,305
 288,013
 767,023
 741,139
Total refined product revenues 4,115,901
 4,309,588
 11,976,551
 12,171,359
Excess crude oil revenues (4)
 264,675
 422,122
 997,988
 1,074,928
Transportation and logistic services 29,868
 25,596
 89,388
 77,799
Other revenues (5)
 14,384
 13,493
 40,763
 46,376
Total sales and other revenues $4,424,828
 $4,770,799
 $13,104,690
 $13,370,462

  Three Months Ended
June 30,		 Six Months Ended
June 30,
  2020 2019 2020 2019
  (In thousands)
Revenues by type        
Refined product revenues        
Transportation fuels (1)
 $1,385,246
 $3,633,966
 $3,863,593
 $6,441,407
Specialty lubricant products (2)
 340,284
 507,183
 811,237
 951,525
Asphalt, fuel oil and other products (3)
 145,298
 248,861
 346,641
 467,718
Total refined product revenues 1,870,828
 4,390,010
 5,021,471
 7,860,650
Excess crude oil revenues (4)
 163,394
 350,683
 363,173
 733,313
Transportation and logistic services 19,244
 28,382
 45,670
 59,520
Other revenues (5)
 9,464
 13,540
 33,161
 26,379
Total sales and other revenues $2,062,930
 $4,782,615
 $5,463,475
 $8,679,862
 Three Months Ended
September 30,		 Nine Months Ended
September 30,		 Three Months Ended
June 30,		 Six Months Ended
June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
 (In thousands) (In thousands)
Refined product revenues by market                
United States                
Mid-Continent $2,191,014
 $2,337,689
 $6,283,488
 $6,458,935
 $867,660
 $2,361,969
 $2,400,584
 $4,092,474
Southwest 913,326
 1,016,771
 2,772,281
 2,865,324
 436,073
 1,008,806
 1,170,248
 1,858,955
Rocky Mountains 611,003
 627,542
 1,739,401
 1,869,414
 274,973
 613,063
 743,752
 1,128,398
Northeast 151,919
 85,344
 427,926
 261,380
 110,909
 148,116
 270,733
 276,007
Canada 184,784
 190,727
 536,911
 563,088
 120,870
 174,772
 303,523
 352,127
Europe, Asia and Latin America 63,855
 51,515
 216,544
 153,218
 60,343
 83,284
 132,631
 152,689
Total refined product revenues $4,115,901
 $4,309,588
 $11,976,551
 $12,171,359
 $1,870,828
 $4,390,010
 $5,021,471
 $7,860,650

(1)Transportation fuels consist of gasoline, diesel and jet fuel.
(2)Specialty lubricant products consist of base oil, waxes, finished lubricants and other specialty fluids.
(3)Asphalt, fuel oil and other products revenue include revenues attributable to our Refining and Lubricants and Specialty Products segments of $231.4$131.9 million and $67.9$13.4 million, respectively, for the three months ended SeptemberJune 30, 2019, $612.02020, $280.7 million and $155.0$65.9 million, respectively for the ninesix months ended SeptemberJune 30, 2019, $234.92020, $210.7 million and $53.1$38.2 million, respectively, for the three months ended SeptemberJune 30, 2018,2019, and $589.7$380.6 million and $151.4$87.2 million, respectively, for the ninesix months ended SeptemberJune 30, 2018.2019.
(4)Excess crude oil revenues represent sales of purchased crude oil inventory that at times exceeds the supply needs of our refineries.
(5)Other revenues are principally attributable to our Refining segment.


Our consolidated balance sheet reflects contract liabilities related to unearned revenues attributable to future service obligations under HEP’s third-party transportation agreements and production agreements from the acquisition of Sonneborn on February 1, 2019. The following table presents changes to our contract liabilities during the ninesix months ended SeptemberJune 30, 2020 and 2019.

  January 1, 2019 Sonneborn Acquisition Increase Recognized as Revenue September 30, 2019
  (In thousands)
Accrued liabilities $132
 6,463
 $19,255
 $(21,135) $4,715
  Six Months Ended June 30,
  2020 2019
  (In thousands)
Balance at January 1 $4,652
 $132
Sonneborn acquisition —
 6,463
Increase 16,115
 10,813
Recognized as revenue (14,980) (12,906)
Balance at June 30 $5,787
 $4,502


As of SeptemberJune 30, 2019,2020, we have long-term contracts with customers that specify minimum volumes of gasoline, diesel, lubricants and specialty products to be sold ratably at market prices through 2021.2024. Such volumes are typically nominated in the month preceding delivery and delivered ratably throughout the following month. Future prices are subject to market fluctuations and therefore, we have elected the exemption to exclude variable consideration under these contracts under Accounting Standards Codification 606-10-50-14A. Aggregate minimum volumes expected to be sold (future performance obligations) under our long-term product sales contracts with customers are as follows:

  Remainder of 2019 2020 2021 Thereafter Total
  (In thousands)
Refined product sales volumes (barrels) 5,610
 7,964
 1,847
 —
 15,421
  Remainder of 2020 2021 2022 Thereafter Total
  (In thousands)
Refined product sales volumes (barrels) 10,398
 15,958
 12,799
 24,465
 63,620


Additionally, HEP has long-term contracts with third-party customers that specify minimum volumes of product to be transported through its pipelines and terminals that result in fixed-minimum annual revenues through 2022.2025. Annual minimum revenues attributable to HEP’s third-party contracts as of SeptemberJune 30, 20192020 are presented below:

  Remainder of 2019 2020 2021 Thereafter Total
  (In thousands)
HEP contractual minimum revenues $10,695
 $28,238
 $22,822
 $38,575
 $100,330
  Remainder of 2020 2021 2022 Thereafter Total
  (In thousands)
HEP contractual minimum revenues $13,164
 $21,942
 $10,954
 $20,293
 $66,353



NOTE 6:4:Fair Value Measurements

Our financial instruments measured at fair value on a recurring basis consist of derivative instruments and RINs credit obligations.

Fair value measurements are derived using inputs (assumptions that market participants would use in pricing an asset or liability, including assumptions about risk). GAAP categorizes inputs used in fair value measurements into three broad levels as follows:

(Level 1) Quoted prices in active markets for identical assets or liabilities.
(Level 2) Observable inputs other than quoted prices included in Level 1, such as quoted prices for similar assets and liabilities in active markets, similar assets and liabilities in markets that are not active or can be corroborated by observable market data.
(Level 3) Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes valuation techniques that involve significant unobservable inputs.


The carrying amounts of derivative instruments and RINs credit obligations at SeptemberJune 30, 20192020 and December 31, 20182019 were as follows:
    Fair Value by Input Level
  Carrying Amount Level 1 Level 2 Level 3
  (In thousands)
September 30, 2019        
Assets:        
NYMEX futures contracts $2,976
 $2,976
 $—
 $—
Foreign currency forward contracts 2,511
 —
 2,511
 —
Commodity price swaps 18,007
 —
 18,007
 —
Commodity forward contracts 1,453
 —
 1,453
 —
Total assets $24,947
 $2,976
 $21,971
 $—
         
Liabilities:        
Foreign currency forward contracts $17
 $—
 $17
 $—
Commodity price swaps 1,094
 —
 1,094
 —
Commodity forward contracts 1,367
 —
 1,367
 —
Total liabilities $2,478
 $—
 $2,478
 $—

    Fair Value by Input Level
  Carrying Amount Level 1 Level 2 Level 3
  (In thousands)
June 30, 2020        
Assets:        
Commodity price swaps $3,561
 $—
 $3,561
 $—
Commodity forward contracts 4,219
 —
 4,219
 —
Foreign currency forward contracts 7,361
 —
 7,361
 —
Total assets $15,141
 $—
 $15,141
 $—
         
Liabilities:        
NYMEX futures contracts $6,987
 $6,987
 $—
 $—
Commodity price swaps 395
 —
 395
 —
Commodity forward contracts 6,156
 —
 6,156
 —
RINs credit obligations (1)
 5,349
 —
 5,349
 —
Total liabilities $18,887
 $6,987
 $11,900
 $—
   Fair Value by Input Level   Fair Value by Input Level
Financial Instrument Carrying Amount Level 1 Level 2 Level 3
(In thousands) Carrying Amount Level 1 Level 2 Level 3
December 31, 2018        
(In thousands)
December 31, 2019        
Assets:                
NYMEX futures contracts $2,473
 $2,473
 $—
 $—
Foreign currency forward contracts 25,956
 —
 25,956
 —
Commodity price swaps 10,817
 —
 10,817
 —
 $13,455
 $—
 $13,455
 $—
Commodity forward contracts 1,034
 —
 1,034
 $—
 4,133
 —
 4,133
 $—
Total assets $40,280
 $2,473
 $37,807
 $—
 $17,588
 $—
 $17,588
 $—
                
Liabilities:                
NYMEX futures contracts $2,578
 $2,578
 $—
 $—
Commodity price swaps $956
 $—
 $956
 $—
 1,230
 —
 1,230
 —
Commodity forward contracts 1,137
 —
 1,137
 —
 3,685
 —
 3,685
 —
RINs credit obligations (1)
 4,084
 —
 4,084
 —
Foreign currency forward contracts 6,722
 —
 6,722
 —
Total liabilities $6,177
 $—
 $6,177
 $—
 $14,215
 $2,578
 $11,637
 $—


(1)Represent obligations for RINs credits for which we did not have sufficient quantities at December 31, 2018 to satisfy our Environmental Protection Agency (“EPA”) regulatory blending requirements.
(1) Represent obligations for RINs credits for which we did not have sufficient quantities at June 30, 2020 to satisfy our EPA regulatory blending requirements.

Level 1 Instruments
Our NYMEX futures contracts are exchange traded and are measured and recorded at fair value using quoted market prices, a Level 1 input.

Level 2 Instruments
Derivative instruments consisting of foreign currency forward contracts, commodity price swaps and forward sales and purchase contracts are measured and recorded at fair value using Level 2 inputs. The fair value of the commodity price swap contracts is based on the net present value of expected future cash flows related to both variable and fixed rate legs of the respective swap agreements. The measurements are computed using market-based observable input and quoted forward commodity prices with respect to our commodity price swaps. RINs credit obligations are valued based on current market RINs prices. The fair value of foreign currency forward contracts are based on values provided by a third party, which were derived using market quotes for similar type instruments, a Level 2 input.


Nonrecurring Fair Value Measurements
During the three months ended June 30, 2020, we recognized long-lived asset impairment charges based on fair value measurements utilized during our goodwill and long-lived asset impairment testing (see Note 1). The fair value measurements were based on a combination of valuation methods including discounted cash flows, the guideline public company and guideline transaction methods and obsolescence adjusted replacement costs, all of which are Level 3 inputs.

During the three months ended June 30, 2020, HEP recognized a gain on sales-type leases (see Note 2). The estimated fair value of the underlying leased assets at contract inception and the present value of the estimated unguaranteed residual asset at the end of the lease term were used in determining the net investment in leases and related recognized gain on sales-type leases. The asset valuation estimates included Level 3 inputs based on a replacement cost valuation method.



NOTE 7:5:Earnings Per Share

Basic earnings per share is calculated as net income (loss) attributable to HollyFrontier stockholders divided by the average number of shares of common stock outstanding. Diluted earnings per share assumes, when dilutive, the issuance of the net incremental shares from restricted sharesstock units and performance share units. The following is a reconciliation of the denominators of the basic and diluted per share computations for net income (loss) attributable to HollyFrontier stockholders:
  Three Months Ended
September 30,		 Nine Months Ended
September 30,
  2019 2018 2019 2018
  (In thousands, except per share data)
Net income attributable to HollyFrontier stockholders $261,813
 $342,466
 $711,783
 $956,064
Participating securities’ (restricted stock) share in earnings 385
 1,171
 1,033
 3,321
Net income attributable to common shares $261,428
 $341,295
 $710,750
 $952,743
Average number of shares of common stock outstanding 163,676
 175,097
 167,935
 175,865
Effect of dilutive variable restricted shares and performance share units (1)
 1,335
 1,830
 1,190
 1,692
Average number of shares of common stock outstanding assuming dilution 165,011
 176,927
 169,125
 177,557
Basic earnings per share $1.60
 $1.95
 $4.23
 $5.42
Diluted earnings per share $1.58
 $1.93
 $4.20
 $5.37
(1) Excludes anti-dilutive restricted and performance share units of:
 109
 —
 120
 2
  Three Months Ended
June 30,		 Six Months Ended
June 30,
  2020 2019 2020 2019
  (In thousands, except per share data)
Net income (loss) attributable to HollyFrontier stockholders $(176,677) $196,915
 $(481,300) $449,970
Participating securities’ (restricted stock) share in earnings —
 283
 —
 647
Net income (loss) attributable to common shares $(176,677) $196,632
 $(481,300) $449,323
Average number of shares of common stock outstanding 161,889
 169,356
 161,882
 170,100
Effect of dilutive variable restricted stock units and performance share units (1)
 —
 1,191
 —
 1,164
Average number of shares of common stock outstanding assuming dilution 161,889
 170,547
 161,882
 171,264
Basic earnings (loss) per share $(1.09) $1.16
 $(2.97) $2.64
Diluted earnings (loss) per share $(1.09) $1.15
 $(2.97) $2.62
(1) Excludes anti-dilutive restricted and performance share units of:
 590
 160
 585
 131



NOTE 8:6:Stock-Based Compensation

We have a principal share-based compensation plan (the “Long-Term“2020 Long-Term Incentive Compensation Plan”)., which allows us to grant new equity awards until February 12, 2030. We also have a long-term incentive compensation plan which expires pursuant to its terms on December 31, 2020 and will continue to govern outstanding equity awards granted thereunder; however, as of February 12, 2020, no new awards are being granted under this plan. The compensation cost charged against income for the planthese plans was $9.28.1 million and $8.1$11.9 million for the three months ended SeptemberJune 30, 20192020 and 2018,2019, respectively, and $30.0$12.9 million and $23.8$20.8 million for the ninesix months ended SeptemberJune 30, 20192020 and 2018,2019, respectively. Our accounting policy for the recognition of compensation expense for awards with pro-rata vesting is to expense the costs ratably over the vesting periods.

Additionally, HEP maintains a share-based compensation plan for Holly Logistic Services, L.L.C.’s non-employee directors and certain executives and employees. Compensation cost attributable to HEP’s share-based compensation plan was $0.5 million and $0.7$0.6 million for the three months ended SeptemberJune 30, 20192020 and 2018,2019, respectively, and $1.8$1.0 million and $2.3$1.2 million for the ninesix months ended SeptemberJune 30, 20192020 and 2018,2019, respectively.

Restricted Stock and Restricted Stock Units
Under our Long-Term Incentive Compensation Plan,long-term incentive plan, we grant certain officers and other key employees restricted stock unit awards, with awardswhich are payable in stock or cash and generally vesting over a period of three years. We previously granted restricted stock to certain officers and key employees with awards vestingvest over a period of three years. Certain restricted stock unit award recipients have the right to receive dividends, however, restricted stock units do not have any other rights of absolute ownership. Restricted stock award recipients are generally entitled to all the rights of absolute ownership of the restricted shares from the date of grant including the right to vote the shares and to receive dividends. Upon vesting, restrictions on the restricted stock and restricted stock units lapse at which time they convert to common shares or cash. In addition, we grant non-employee directors restricted stock unit awards, which typically vest over a period of one year and are payable in stock. The fair value of each restricted stock and restricted stock unit award is measured based on the grant date market price of our common shares and is amortized over the respective vesting period. We account for forfeitures on an estimated basis.



A summary of restricted stock and restricted stock unit activity during the ninesix months ended SeptemberJune 30, 20192020 is presented below:
Restricted Stock and Restricted Stock Units Grants Weighted Average Grant Date Fair Value Aggregate Intrinsic Value ($000)
       
Outstanding at January 1, 2019 (non-vested) 1,196,914
 $46.81
  
Granted 45,006
 52.97
  
Vesting (transfer/conversion to common stock) (17,374) 49.32
  
Forfeited (38,600) 47.97
  
Outstanding at September 30, 2019 (non-vested) 1,185,946
 46.97
 $63,614
Restricted Stock Units Grants Weighted Average Grant Date Fair Value Aggregate Intrinsic Value ($000)
       
Outstanding at January 1, 2020 1,101,781
 $53.30
  
Granted 62,776
 35.58
  
Vested (79,956) 44.30
  
Forfeited (59,494) 53.41
  
Converted from performance share units 19,450
 38.13
  
Outstanding at June 30, 2020 1,044,557
 52.48
 $30,501

For the ninesix months ended SeptemberJune 30, 20192020, restricted stock and restricted stock units vested having a grant date fair value of $0.9$3.5 million. As of SeptemberJune 30, 20192020, there was $14.4$23.2 million of total unrecognized compensation cost related to non-vested restricted stock and restricted stock unit grants. That cost is expected to be recognized over a weighted-average period of 1.01.2 years.

Performance Share Units
Under our Long-Term Incentive Compensation Plan,long-term incentive plan, we grant certain officers and other key employees performance share units, which are payable in stock or cash upon meeting certain criteria over the service period, and generally vest over a period of three years. Under the terms of our performance share unit grants, awards are subject to “financial performance” and “market performance” criteria. Financial performance is based on our financial performance compared to a peer group of independent refining companies, while market performance is based on the relative standing of total shareholder return achieved by HollyFrontier compared to peer group companies. The number of shares ultimately issued or cash paid under these awards can range from 0 to 200% of target award amounts. Holders of performance share units have the right to receive dividend equivalents and other distributions with respect to such performance share units based on the target level of payout.

A summary of performance share unit activity and changes during the ninesix months ended SeptemberJune 30, 20192020 is presented below:
Performance Share Units Grants
   
Outstanding at January 1, 2019 (non-vested)2020 662,431375,588
GrantedVested 6,086(12,129
)
Forfeited (4,51618,766)
Converted to restricted stock units(19,450)
Outstanding at SeptemberJune 30, 2019 (non-vested)2020 664,001325,243


For the six months June 30, 2020, we issued 7,889 shares of common stock, representing a 100% payout on vested performance share units having a grant date fair value of $0.5 million. As of SeptemberJune 30, 2019,2020, there was $7.9$8.3 million of total unrecognized compensation cost related to non-vested performance share units having a grant date fair value of $47.24$58.07 per unit. That cost is expected to be recognized over a weighted-average period of 0.91.6 years.



NOTE 9:7:Inventories

Inventories consist of the following components:
 September 30,
2019		 December 31, 2018 June 30,
2020		 December 31, 2019
 (In thousands) (In thousands)
Crude oil $472,932
 $503,705
 $537,863
 $489,169
Other raw materials and unfinished products(1)
 306,504
 360,124
 301,956
 394,045
Finished products(2)
 860,130
 662,713
 668,955
 639,938
Lower of cost or market reserve (209,655) (360,138) (530,923) (240,363)
Process chemicals(3)
 29,040
 31,413
 33,677
 36,786
Repair and maintenance supplies and other (4)
 178,108
 156,562
 162,173
 154,627
Total inventory $1,637,059
 $1,354,379
 $1,173,701
 $1,474,202

(1)Other raw materials and unfinished products include feedstocks and blendstocks, other than crude.
(2)Finished products include gasolines, jet fuels, diesels, lubricants, asphalts, LPG’s and residual fuels.
(3)Process chemicals include additives and other chemicals.
(4)Includes RINs.

Our inventories that are valued at the lower of LIFO cost or market reflect a valuation reserve of $209.7$530.9 million and $360.1$240.4 million at SeptemberJune 30, 20192020 and December 31, 2018,2019, respectively. The December 31, 20182019 market reserve of $360.1$240.4 million was reversed due to the sale of inventory quantities that gave rise to the 20182019 reserve. A new market reserve of $209.7$530.9 million was established as of SeptemberJune 30, 20192020 based on market conditions and prices at that time. The effect of the change in lower of cost or market reserve was a decrease to cost of products sold totaling $269.9 million for the three months ended June 30, 2020 and an increase to cost of products sold totaling $34.1 million and $17.8$47.8 million for the three months ended SeptemberJune 30, 2019, respectively, and 2018, respectively,an increase to cost of products sold totaling $290.6 million for the six months ended June 30, 2020 and a decrease to cost of products sold totaling $150.5 million and $192.9$184.5 million for the ninesix months ended SeptemberJune 30, 2019, and 2018, respectively.

At SeptemberJune 30, 2019,2020, the LIFO value of inventory, net of the lower of cost or market reserve, was equal to current costs.

DuringIn connection with our announcement of the three months ended September 30, 2019, the EPA granted theconversion of our Cheyenne Refinery and the Woods Cross Refinery each a one-year small refinery exemption from the Renewable Fuel Standard (“RFS”) program requirements for the 2018 calendar year end. As a result, the Cheyenne Refinery’s and the Woods Cross Refinery’s gasoline andto renewable diesel production, are not subject to the Renewable Volume Obligation (“RVO”) for 2018. In the third quarterwe recorded a reserve of 2019, we increased$6.2 million against our inventory of RINsrepair and reduced our cost of products sold by $36.6 million representing the net cost of the RINsmaintenance supplies inventory. This charge to cost of products soldwas recorded in 2018, less the loss incurred for selling 2018 vintage RINsoperating expenses in excess of those which we can use subject to the 20% carryover limit.

During the three months ended June 30, 2018, the EPA granted the Woods Cross Refinery a one-year small refinery exemption from the RFS program requirements for the 2017 calendar year end. As a result, the Woods Cross Refinery’s gasoline and diesel production are not subject to the RVO for 2017. In the second quarter of 2018, we increased our inventory of RINs and reduced our cost of products sold by $25.3 million, representing the net cost of the Woods Cross Refinery’s RINs charge to cost of products sold in 2017, less the loss incurred for selling 2017 vintage RINs in excess of those which we can use subject to the 20% carryover limit.

During the three months ended March 31, 2018, the EPA granted the Cheyenne Refinery a one-year small refinery exemption from the RFS program requirements for the 2015 and 2017 calendar years end. As a result, the Cheyenne Refinery’s gasoline and diesel production are not subject to the RVO for those years. At the date we received the 2017 Cheyenne Refinery exemption, we had not yet retired RINs to satisfy the 2017 RVO, which we intended to satisfy, in part, with 2016 vintage RINs subject to the 20% carryover limit. In the first quarter of 2018, we increased our inventory of RINs and reduced our cost of products sold by $37.9 million, representing the net cost of the Cheyenne Refinery’s RINs charged to cost of products sold in 2017, less the loss incurred from selling 2016 vintage RINs prior to their expiration in 2018.


In the first quarter of 2018, the EPA provided us 2018 vintage RINs to replace the RINs previously submitted to meet the Cheyenne Refinery’s 2015 RVO. In the first quarter of 2018, we increased our inventory of RINs and reduced our cost of products sold by $33.8 million representing the fair value of the 2018 replacement RINs obtained from the Cheyenne Refinery’s exemption of its 2015 RVO.

Various subsidiaries of HollyFrontier have intervened in three lawsuits brought by renewable fuel interest groups against the EPA in federal appellate courts alleging violations of the RFS under the Clean Air Act and challenging the EPA’s handling of small refinery exemptions. We believe the EPA correctly applied applicable law to the matters at issue and will vigorously defend the EPA’s position on small refinery exemptions. It is too early to assess whether the cases are expected to have any impact on us.2020.


NOTE 10:8:Environmental

Environmental costs are charged to operating expenses if they relate to an existing condition caused by past operations and do not contribute to current or future revenue generation. We have ongoing investigations of environmental matters at various locations and routinely assess our recorded environmental obligations, if any, with respect to such matters. Liabilities are recorded when site restoration and environmental remediation, cleanup and other obligations are either known or considered probable and can be reasonably estimated. Such estimates are undiscounted and require judgment with respect to costs, time frame and extent of required remedial and cleanup activities and are subject to periodic adjustments based on currently available information. Recoveries of environmental costs through insurance, indemnification arrangements or other sources are included in other assets to the extent such recoveries are considered probable.

We incurred expense of $1.8$0.4 million and $3.3$2.3 million for the three months ended SeptemberJune 30, 20192020 and 2018,2019, respectively, and $5.5$2.0 million and $4.9$3.7 million for the ninesix months ended SeptemberJune 30, 20192020 and 2018,2019, respectively, for environmental remediation obligations. The accrued environmental liability reflected in our consolidated balance sheets was $109.9$115.6 million and $110.2117.7 million at SeptemberJune 30, 20192020 and December 31, 20182019, respectively, of which $92.4$94.1 million and $93.895.6 million, respectively, were classified as other long-term liabilities. These accruals include remediation and monitoring costs expected to be incurred over an extended period of time (up to 30 years for certain projects). Estimated liabilities could increase in the future when the results of ongoing investigations become known, are considered probable and can be reasonably estimated.



NOTE 11:9:Debt

HollyFrontier Credit Agreement
We have a $1.35 billion senior unsecured revolving credit facility maturing in February 2022 (the “HollyFrontier Credit Agreement”). The HollyFrontier Credit Agreement may be used for revolving credit loans and letters of credit from time to time and is available to fund general corporate purposes. At SeptemberJune 30, 20192020, we were in compliance with all covenants, had no outstanding borrowings and had outstanding letters of credit totaling $4.9 million under the HollyFrontier Credit Agreement.

HEP Credit Agreement
HEP has a $1.4 billion senior secured revolving credit facility maturing in July 2022 (the “HEP Credit Agreement”) and is available to fund capital expenditures, investments, acquisitions, distribution payments, working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit and has a $300 million accordion. During the ninesix months ended SeptemberJune 30, 2019,2020, HEP received advances totaling $269.5$168.0 million and repaid $257.0$138.5 million under the HEP Credit Agreement. At SeptemberJune 30, 2019,2020, HEP was in compliance with all of its covenants, had outstanding borrowings of $935.5$995.0 million and no outstanding letters of credit under the HEP Credit Agreement.

HEP’s obligations under the HEP Credit Agreement are collateralized by substantially all of HEP’s assets and are guaranteed by HEP’s material wholly-owned subsidiaries. Any recourse to the general partner would be limited to the extent of HEP Logistics Holdings, L.P.’s assets, which other than its investment in HEP are not significant. HEP’s creditors have no recourse to our other assets. Furthermore, our creditors have no recourse to the assets of HEP and its consolidated subsidiaries.

HollyFrontier Senior Notes
Our 5.875% senior notes ($1 billion aggregate principal amount maturing April 2026) (the “HollyFrontier Senior Notes”) are unsecured and unsubordinated obligations of ours and rank equally with all our other existing and future unsecured and unsubordinated indebtedness.


HollyFrontier Financing Arrangements
In December 2018, certain of our wholly-owned subsidiaries entered into financing arrangements whereby such subsidiaries sold a portion of their precious metals catalyst to a financial institution and then leased back the precious metals catalyst in exchange for total cash received of $32.5 million. The volume of the precious metals catalyst and the lease rate are fixed over the one-year term of each lease, and the lease payments are recorded as interest expense. AtThe leases mature on February 1, 2021. Upon maturity, we must repurchaseeither satisfy the precious metals catalystobligation at its then fair market value.value or refinance to extend the maturity. These financing arrangements are recorded at a Level 2 fair value totaling $36.5$35.0 million and $40.0 million at SeptemberJune 30, 2020 and December 31, 2019, respectively, and are included in “Accrued liabilities” in our consolidated balance sheets. See Note 64 for additional information on Level 2 inputs.

HEP Senior Notes
HEP’s 6.0%On February 4, 2020, HEP closed a private placement of $500 million in aggregate principal amount of 5.0% HEP senior unsecured notes ($500maturing February 2028 (the “HEP Senior Notes”). On February 5, 2020, HEP redeemed its existing $500 million aggregate principal amount of 6.0% senior notes maturing August 2024) (the “HEP2024 at a redemption cost of $522.5 million. HEP recognized a $25.9 million early extinguishment loss consisting of a $22.5 million debt redemption premium and unamortized discount and financing costs of $3.4 million. HEP funded the $522.5 million redemption with proceeds from the issuance of its 5.0% senior notes and borrowings under the HEP Credit Agreement.

The HEP Senior Notes”)Notes are unsecured and impose certain restrictive covenants, including limitations on HEP’s ability to incur additional indebtedness, make investments, sell assets, incur certain liens, pay distributions, enter into transactions with affiliates, and enter into mergers. HEP was in compliance with the restrictive covenants for the HEP Senior Notes as of June 30, 2020. At any time when the HEP Senior Notes are rated investment grade by botheither Moody’s andor Standard & Poor’s and no default or event of default exists, HEP will not be subject to many of the foregoing covenants. Additionally, HEP has certain redemption rights at varying premiums over face value under the HEP Senior Notes.

Indebtedness under the HEP Senior Notes is guaranteed by HEP’s wholly-owned subsidiaries. HEP’s creditors have no recourse to our assets. Furthermore, our creditors have no recourse to the assets of HEP and its consolidated subsidiaries.


The carrying amounts of long-term debt are as follows:
 September 30,
2019		 December 31,
2018		 June 30,
2020		 December 31,
2019
 (In thousands) (In thousands)
HollyFrontier 5.875% Senior Notes        
Principal $1,000,000
 $1,000,000
 $1,000,000
 $1,000,000
Unamortized discount and debt issuance costs (6,635) (7,360) (5,902) (6,391)
 993,365
 992,640
 994,098
 993,609
        
HEP Credit Agreement 935,500
 923,000
 995,000
 965,500
        
HEP 6% Senior Notes    
HEP 5.0% Senior Notes    
Principal 500,000
 —
Unamortized discount and debt issuance costs (8,352) —
 491,648
 —
    
HEP 6.0% Senior Notes    
Principal 500,000
 500,000
 —
 500,000
Unamortized discount and debt issuance costs (3,631) (4,100) —
 (3,469)
 496,369
 495,900
 —
 496,531
        
Total HEP long-term debt 1,431,869
 1,418,900
 1,486,648
 1,462,031
        
Total long-term debt $2,425,234
 $2,411,540
 $2,480,746
 $2,455,640

The fair values of the senior notes are as follows:
 September 30,
2019		 December 31,
2018		 June 30,
2020		 December 31,
2019
 (In thousands) (In thousands)
        
HollyFrontier senior notes $1,121,460
 $1,019,160
 $1,105,120
 $1,127,610
        
HEP senior notes $523,220
 $488,310
 $477,835
 $522,045


These fair values are based on a Level 2 input. See Note 64 for additional information on Level 2 inputs.


We capitalized interest attributable to construction projects of $0.7$0.8 million and $1.3$0.5 million for the three months ended SeptemberJune 30, 20192020 and 20182019, respectively, and $1.8$1.4 million and $3.3$1.1 million for the ninesix months ended SeptemberJune 30, 20192020 and 20182019, respectively.


NOTE 12:10: Derivative Instruments and Hedging Activities

Commodity Price Risk Management
Our primary market risk is commodity price risk. We are exposed to market risks related to the volatility in crude oil and refined products, as well as volatility in the price of natural gas used in our refining operations. We periodically enter into derivative contracts in the form of commodity price swaps, forward purchase and sales and futures contracts to mitigate price exposure with respect to our inventory positions, natural gas purchases, sales prices of refined products and crude oil costs.

Foreign Currency Risk Management
We are exposed to market risk related to the volatility in foreign currency exchange rates. We periodically enter into derivative contracts in the form of foreign exchange forward and foreign exchange swap contracts to mitigate the exposure associated with fluctuations on intercompany notes with our foreign subsidiaries that are not denominated in the U.S. dollar.


Accounting Hedges
We have swap contracts serving as cash flow hedges against price risk on forecasted purchases of natural gas and to lock in basis spread differentials on forecasted purchases of crude oil. We also periodically have forward sales contracts that lock in the prices of future sales of crude oil and refined product. These contracts have been designated as accounting hedges and are measured at fair value with offsetting adjustments (gains/losses) recorded directly to other comprehensive income. These fair value adjustments are later reclassified to earnings as the hedging instruments mature.

The following table presents the pre-tax effect on other comprehensive income (“OCI”) and earnings due to fair value adjustments and maturities of derivatives designated as hedging instruments under hedge accounting:
 Net Unrealized Gain (Loss) Recognized in OCI Gain (Loss) Reclassified into Earnings Net Unrealized Gain (Loss) Recognized in OCI Gain (Loss) Reclassified into Earnings
Derivatives Designated as Cash Flow Hedging Instruments Three Months Ended
September 30,		 Income Statement Location Three Months Ended
September 30,		 Three Months Ended
June 30,		 Income Statement Location Three Months Ended
June 30,
2019 2018 2019 2018 2020 2019 2020 2019
 (In thousands) (In thousands)
Commodity contracts $(7,562) $5,792
 Sales and other revenues $—
 $(1,422) $6,914
 $(6,014) Sales and other revenues $(5,403) $—
     Cost of products sold 6,027
 —
     Cost of products sold 459
 5,674
     Operating expenses (454) (209)     Operating expenses (457) (353)
Total $(7,562) $5,792
 $5,573
 $(1,631) $6,914
 $(6,014) $(5,401) $5,321


  Net Unrealized Gain (Loss) Recognized in OCI Gain (Loss) Reclassified into Earnings
Derivatives Designated as Cash Flow Hedging Instruments Nine Months Ended
September 30,		 Income Statement Location Nine Months Ended
September 30,
 2019 2018  2019 2018
  (In thousands)
Commodity contracts $372
 $1,796
 Sales and other revenues $(1,799) $(5,093)
      Cost of products sold 15,323
 —
      Operating expenses (987) (945)
Total $372
 $1,796
   $12,537
 $(6,038)


  Net Unrealized Gain (Loss) Recognized in OCI Gain (Loss) Reclassified into Earnings
Derivatives Designated as Cash Flow Hedging Instruments Six Months Ended
June 30,		 Income Statement Location Six Months Ended
June 30,
 2020 2019  2020 2019
  (In thousands)
Commodity contracts $(6,410) $7,934
 Sales and other revenues $49
 $(1,799)
      Cost of products sold 2,289
 9,295
      Operating expenses (1,163) (533)
Total $(6,410) $7,934
   $1,175
 $6,963

Economic Hedges
We have commodity contracts including contracts to lock in basis spread differentials on forecasted purchases of crude oil, swap contracts to lock in the crack spread of WTI and gasoline, NYMEX futures contracts to lock in prices on forecasted purchases and sales of inventory and forward purchase and sell contracts that serve as economic hedges (derivatives used for risk management, but not designated as accounting hedges). We also have forward currency contracts to fix the rate of foreign currency. In addition, our catalyst financing arrangements discussed in Note 119 could require repayment under certain conditions based on the futures pricefuture pricing of platinum, which is an embedded derivative. These contracts are measured at fair value with offsetting adjustments (gains/losses) recorded directly to income.

The following table presents the pre-tax effect on income due to maturities and fair value adjustments of our economic hedges:
 Gain (Loss) Recognized in Earnings Gain (Loss) Recognized in Earnings
Derivatives Not Designated as Hedging Instruments Income Statement Location Three Months Ended
September 30,		 Nine Months Ended
September 30,		 Income Statement Location Three Months Ended
June 30,		 Six Months Ended
June 30,
2019 2018 2019 2018 2020 2019 2020 2019
 (In thousands) (In thousands)
Commodity contracts Cost of products sold $8,640
 $(8,252) $1,561
 $(20,580) Cost of products sold $(7,180) $338
 $17,909
 $(7,079)
 Interest expense (1,720) —
 (2,995) —
 Interest expense (5,100) 741
 4,712
 (1,275)
Foreign currency contracts Gain on foreign currency transactions 5,713
 (7,052) (8,983) 18,504
 Gain (loss) on foreign currency transactions (14,315) (7,090) 19,160
 (14,696)
 Total $12,633
 $(15,304) $(10,417) $(2,076) Total $(26,595) $(6,011) $41,781
 $(23,050)



As of SeptemberJune 30, 2019,2020, we have the following notional contract volumes related to outstanding derivative instruments:
    Notional Contract Volumes by Year of Maturity  
  Total Outstanding Notional 2019 2020 2021 Unit of Measure
Derivatives Designated as Hedging Instruments          
Natural gas price swaps - long 4,050,000
 450,000
 1,800,000
 1,800,000
 MMBTU
Crude oil price swaps (basis spread) - long 5,954,000
 1,196,000
 4,758,000
 —
 Barrels
Forward crude oil contracts - short 423,739
 423,739
 —
 —
 Barrels
           
Derivatives Not Designated as Hedging Instruments          
NYMEX futures (WTI) - short 1,825,000
 1,713,000
 112,000
 —
 Barrels
Crude oil price swaps (basis spread) - long 1,464,000
 —
 1,464,000
 —
 Barrels
WTI and gasoline crack spread swaps - short 200,000
 200,000
 —
 —
 Barrels
Forward gasoline and diesel contracts - long 538,500
 538,500
 —
 —
 Barrels
Forward crude oil contracts - long 140,849
 140,849
 —
 —
 Barrels
Physical contracts - long 350,000
 350,000
 —
 —
 Barrels
Physical contracts - short 350,000
 350,000
 —
 —
 Barrels
Foreign currency forward contracts 434,443,896
 114,213,501
 320,230,395
 —
 U.S. dollar
Forward commodity contracts (platinum) 41,147
 41,147
 —
 —
 Troy ounces

    Notional Contract Volumes by Year of Maturity  
  Total Outstanding Notional 2020 2021 Unit of Measure
Derivatives Designated as Hedging Instruments        
Natural gas price swaps - long 2,700,000
 900,000
 1,800,000
 MMBTU
Crude oil price swaps (basis spread) - long 2,392,000
 2,392,000
 —
 Barrels
Forward diesel contracts - short 200,000
 200,000
 —
 Barrels
         
Derivatives Not Designated as Hedging Instruments        
NYMEX futures (WTI) - short 890,000
 890,000
 —
 Barrels
Crude oil price swaps (basis spread) - long 736,000
 736,000
 —
 Barrels
Forward gasoline and diesel contracts - long 464,000
 464,000
 —
 Barrels
Foreign currency forward contracts 422,074,120
 214,491,576
 207,582,544
 U.S. dollar
Forward commodity contracts (platinum) 40,867
 —
 40,867
 Troy ounces

The following table presents the fair value and balance sheet locations of our outstanding derivative instruments. These amounts are presented on a gross basis with offsetting balances that reconcile to a net asset or liability position in our consolidated balance sheets. We present on a net basis to reflect the net settlement of these positions in accordance with provisions of our master netting arrangements.
 Derivatives in Net Asset Position Derivatives in Net Liability Position Derivatives in Net Asset Position Derivatives in Net Liability Position
 Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet
   (In thousands)     (In thousands)  
September 30, 2019            
June 30, 2020            
Derivatives designated as cash flow hedging instruments:Derivatives designated as cash flow hedging instruments:  Derivatives designated as cash flow hedging instruments:  
Commodity price swap contracts $13,182
 $(1,576) $11,606
 $1,614
 $(500) $1,114
 $1,800
 $(1,194) $606
 $395
 $—
 $395
Commodity forward contracts —
 —
 —
 258
 —
 258
 —
 —
 —
 2,134
 —
 2,134
 $13,182
 $(1,576) $11,606
 $1,872
 $(500) $1,372
 $1,800
 $(1,194) $606
 $2,529
 $—
 $2,529
                        
Derivatives not designated as cash flow hedging instruments:Derivatives not designated as cash flow hedging instruments:  Derivatives not designated as cash flow hedging instruments:  
Foreign currency forward contracts $2,511
 $—
 $2,511
 $17
 $—
 $17
NYMEX futures contracts 2,976
 —
 2,976
 —
 —
 —
 $—
 $—
 $—
 $6,987
 $—
 $6,987
Commodity price swap contracts 6,401
 —
 6,401
 —
 (20) (20) 2,955
 —
 2,955
 —
 —
 —
Commodity forward contracts 1,453
 —
 1,453
 1,109
 —
 1,109
 4,219
 —
 4,219
 4,022
 —
 4,022
Foreign currency forward contracts 9,765
 (2,404) 7,361
 —
 —
 —
 $13,341
 $—
 $13,341
 $1,126
 $(20) $1,106
 $16,939
 $(2,404) $14,535
 $11,009
 $—
 $11,009
                        
Total net balance     $24,947
     $2,478
     $15,141
     $13,538
                        
Balance sheet classification: Prepayment and other $23,295
 Accrued liabilities $1,922
 Prepayment and other $15,141
 Accrued liabilities $13,143
 Intangibles and other 1,652
 Other long-term liabilities 556
     Other long-term liabilities 395
   $24,947
     $2,478
   $15,141
     $13,538

December 31, 2018  
 Derivatives in Net Asset Position Derivatives in Net Liability Position
 Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet
   (In thousands)  
December 31, 2019December 31, 2019  
Derivatives designated as cash flow hedging instruments:Derivatives designated as cash flow hedging instruments:  Derivatives designated as cash flow hedging instruments:  
Commodity price swap contracts $11,790
 $(973) $10,817
 $1,755
 $(799) $956
 $7,526
 $(1,784) $5,742
 $1,230
 $—
 $1,230
 $11,790
 $(973) $10,817
 $1,755
 $(799) $956
 $7,526
 $(1,784) $5,742
 $1,230
 $—
 $1,230
                        
Derivatives not designated as cash flow hedging instruments:Derivatives not designated as cash flow hedging instruments:  Derivatives not designated as cash flow hedging instruments:  
NYMEX futures contracts $—
 $—
 $—
 $2,578
 $—
 $2,578
Commodity price swap contracts 7,713
 —
 7,713
 —
 —
 —
Commodity forward contracts 4,133
 —
 4,133
 3,685
 —
 3,685
Foreign currency forward contracts $25,956
 $—
 $25,956
 $—
 $—
 $—
 —
 —
 —
 6,722
 —
 6,722
NYMEX futures contracts 2,473
 —
 2,473
 —
 —
 —
Commodity forward contracts 1,034
 —
 1,034
 1,137
 —
 1,137
 $29,463
 $—
 $29,463
 $1,137
 $—
 $1,137
 $11,846
 $—
 $11,846
 $12,985
 $—
 $12,985
                        
Total net balance     $40,280
     $2,093
     $17,588
     $14,215
                        
Balance sheet classification: Prepayment and other $37,982
 Accrued liabilities $1,137
 Prepayment and other $17,588
 Accrued liabilities $12,985
 Intangibles and other 2,298
 Other long-term liabilities 956
     Other long-term liabilities 1,230
   $40,280
     $2,093
   $17,588
     $14,215

At SeptemberJune 30, 20192020, we had a pre-tax net unrealized gainloss of $10.2$1.9 million classified in accumulated other comprehensive income that relates to all accounting hedges having contractual maturities through 2021. Assuming commodity prices remain unchanged, an unrealized gainloss of $10.3$1.5 million will be effectively transferred from accumulated other comprehensive income into the statement of income as the hedging instruments contractually mature over the next twelve-month period.



NOTE 13:11:Equity

In September 2018,November 2019, our Board of Directors approved a $1$1.0 billion share repurchase program, which replaced all existing share repurchase programs, authorizing us to repurchase common stock in the open market or through privately negotiated transactions. The timing and amount of stock repurchases will depend on market conditions and corporate, regulatory and other relevant considerations. This program may be discontinued at any time by the Board of Directors. As of SeptemberJune 30, 2019,2020, we had remaining authorization to repurchase up to $313.2 millionnot repurchased common stock under this stock repurchase program. In addition, we are authorized by our Board of Directors to repurchase shares in an amount sufficient to offset shares issued under our compensation programs.

During the ninesix months ended SeptemberJune 30, 20192020 and 2018,2019, we withheld 5,35929,587 and 12,593,2,484, respectively, shares of our common stock from certain employees. These withholdings were made under the terms of stock-based compensationrestricted stock unit and performance share unit agreements upon vesting, at which time, we concurrently made cash payments to provide funds for the payment offund payroll and income taxes due at the vestingon behalf of share-based awards.officers and employees who elected to have shares withheld from vested amounts to pay such taxes.



NOTE 14:12:Other Comprehensive Income

The components and allocated tax effects of other comprehensive income are as follows:
  Before-Tax 
Tax Expense
(Benefit)
 After-Tax
  (In thousands)
Three Months Ended September 30, 2019      
Net change in foreign currency translation adjustment $(9,311) $(1,959) $(7,352)
Net unrealized loss on hedging instruments (7,562) (1,929) (5,633)
Other comprehensive loss attributable to HollyFrontier stockholders $(16,873) $(3,888) $(12,985)
       
Three Months Ended September 30, 2018      
Net change in foreign currency translation adjustment $8,325
 $1,756
 $6,569
Net unrealized gain on hedging instruments 5,792
 1,478
 4,314
Other comprehensive income attributable to HollyFrontier stockholders $14,117
 $3,234
 $10,883
       
Nine Months Ended September 30, 2019      
Net change in foreign currency translation adjustment $4,212
 $896
 $3,316
Net unrealized gain on hedging instruments 372
 94
 278
Other comprehensive income attributable to HollyFrontier stockholders $4,584
 $990
 $3,594
       
Nine Months Ended September 30, 2018      
Net change in foreign currency translation adjustment $(15,118) $(3,130) $(11,988)
Net unrealized gain on hedging instruments 1,796
 453
 1,343
Other comprehensive loss attributable to HollyFrontier stockholders $(13,322) $(2,677) $(10,645)

  Before-Tax 
Tax Expense
(Benefit)
 After-Tax
  (In thousands)
Three Months Ended June 30, 2020      
Net change in foreign currency translation adjustment $11,710
 $2,488
 $9,222
Net unrealized gain on hedging instruments 6,914
 1,762
 5,152
Other comprehensive income attributable to HollyFrontier stockholders $18,624
 $4,250
 $14,374
       
Three Months Ended June 30, 2019      
Net change in foreign currency translation adjustment $9,160
 $1,950
 $7,210
Net unrealized loss on hedging instruments (6,014) (1,534) (4,480)
Net change in pension and other post-retirement benefit obligations 74
 —
 74
Other comprehensive income attributable to HollyFrontier stockholders $3,220
 $416
 $2,804
       
Six Months Ended June 30, 2020      
Net change in foreign currency translation adjustment $(9,876) $(2,139) $(7,737)
Net unrealized loss on hedging instruments (6,410) (1,636) (4,774)
Net change in pension and other post-retirement benefit obligations (42) (4) (38)
Other comprehensive loss attributable to HollyFrontier stockholders $(16,328) $(3,779) $(12,549)
       
Six Months Ended June 30, 2019      
Net change in foreign currency translation adjustment $13,523
 $2,855
 $10,668
Net unrealized gain on hedging instruments 7,934
 2,023
 5,911
Other comprehensive income attributable to HollyFrontier stockholders $21,457
 $4,878
 $16,579

The following table presents the income statement line item effects for reclassifications out of accumulated other comprehensive income (“AOCI”):
AOCI Component Gain (Loss) Reclassified From AOCI Income Statement Line Item Gain (Loss) Reclassified From AOCI Income Statement Line Item
 (In thousands) 
 Three Months Ended
September 30,		  Three Months Ended June 30, 
 2019 2018  2020 2019 
      (In thousands) 
Hedging instruments:          
Commodity price swaps $—
 $(1,422) Sales and other revenues $(5,403) $—
 Sales and other revenues
 6,027
 —
 Cost of products sold 459
 5,674
 Cost of products sold
 (454) (209) Operating expenses (457) (353) Operating expenses
 5,573
 (1,631)  (5,401) 5,321
 
 1,421
 (416) Income tax expense (benefit) (1,377) 1,357
 Income tax expense (benefit)
Total reclassifications for the period $4,152
 $(1,215) Net of tax $(4,024) $3,964
 Net of tax
          
 Nine Months Ended
September 30,		  Six Months Ended June 30, 
 2019 2018  2020 2019 
     
Hedging instruments:          
Commodity price swaps $(1,799) $(5,093) Sales and other revenues $49
 $(1,799) Sales and other revenues
 15,323
 —
 Cost of products sold 2,289
 9,295
 Cost of products sold
 (987) (945) Operating expenses (1,163) (533) Operating expenses
 12,537
 (6,038)  1,175
 6,963
 
 3,197
 (1,540) Income tax expense (benefit) 300
 1,776
 Income tax expense
Total reclassifications for the period $9,340
 $(4,498) Net of tax $875
 $5,187
 Net of tax



Accumulated other comprehensive income (loss) in the equity section of our consolidated balance sheets includes:
 September 30,
2019		 December 31,
2018		 June 30,
2020		 December 31,
2019
 (In thousands) (In thousands)
Foreign currency translation adjustment $(9,360) $(12,676) $(9,924) $(2,187)
Unrealized loss on pension obligation (1,404) (1,404) (1,798) (1,733)
Unrealized gain on post-retirement benefit obligations 20,358
 20,358
 15,360
 15,333
Unrealized gain on hedging instruments 7,623
 7,345
Unrealized gain (loss) on hedging instruments (1,413) 3,361
Accumulated other comprehensive income $17,217
 $13,623
 $2,225
 $14,774



NOTE 15:13:Post-retirement Plans

PCLI has union and non-union pension plans which are closed to new entrants. In addition, Sonneborn employees in the Netherlands have a defined benefit pension plan which was frozen and all plan participants became inactive in 2016. Our net periodic pension expense consisted of the following components:
 Three Months Ended
September 30,		 Nine Months Ended
September 30,		 Three Months Ended
June 30,		 Six Months Ended
June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
 (In thousands) (In thousands)
Service cost - benefit earned during the period $1,209
 $1,093
 $3,605
 $3,337
 $1,072
 $1,198
 $2,200
 $2,397
Interest cost on projected benefit obligations 450
 556
 1,325
 1,698
 413
 440
 856
 877
Expected return on plan assets (822) (856) (2,441) (2,615) (976) (811) (2,009) (1,621)
Amortization of loss 15
 —
 45
 —
 —
 830
 —
 1,660
Net periodic pension expense $852
 $793
 $2,534
 $2,420
 $509
 $1,657
 $1,047
 $3,313


The expected long-term annual rates of return on plan assets are 5.00%5.75% and 2.20%1.50% for the PCLI and Sonneborn plans, respectively. These rates were used in measuring 20192020 net periodic benefit costs.


We have post-retirement healthcare and other benefits that are available to certain of our employees who satisfy certain age and service requirements. The net periodic benefit credit of our post-retirement healthcare and other benefits plans consisted of the following components
 Three Months Ended
September 30,		 Nine Months Ended
September 30,		 Three Months Ended
June 30,		 Six Months Ended
June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
 (In thousands) (In thousands)
Service cost – benefit earned during the period $387
 $411
 $1,161
 $1,238
 $446
 $386
 $899
 $771
Interest cost on projected benefit obligations 267
 234
 801
 705
 233
 266
 471
 531
Amortization of prior service credit (870) (870) (2,611) (2,611) (870) (870) (1,741) (1,741)
Amortization of gain (22) —
 (66) —
Amortization of (gain) loss 12
 (22) 25
 (44)
Net periodic post-retirement credit $(238) $(225) $(715) $(668) $(179) $(240) $(346) $(483)

The components, other than service cost, of our net periodic pension expense and net periodic post-retirement credit are recorded in Other, net in our consolidated statements of income.

Sonneborn has various post-retirement benefit plans for employees in the United States and in the Netherlands.
The plans for Sonneborn employees in the Netherlands include a defined benefit pension plan which was frozen and all plan participants became inactive in 2016. The plan assets are in the form of a third-party insurance contract that is valued based on the assets held by the insurer and insures a value which approximates the accrued benefits related to the plan’s accumulated benefit obligation. A new multiemployer pension plan was established in 2016, which is accounted for as a defined contribution plan. Also, in 2016, a new plan was established to provide future indexation benefits to participants who had accrued benefits under the expiring arrangements. Such benefits are funded by Sonneborn Refined Products B.V.
The plans for Sonneborn employees in the United States include a post-retirement medical plan and a multiemployer plan for union employees. These plans are accounted for as defined contribution plans.



NOTE 16:14:Contingencies

We are a party to various litigation and legal proceedings which we believe, based on advice of counsel, will not either individually or in the aggregate have a materialmaterially adverse effect on our financial condition, results of operations or cash flows.

In March 2006, a subsidiary of ours sold the assets of Montana Refining Company under an Asset Purchase Agreement (“APA”). Calumet Montana Refining LLC, the current owner of the assets, submitted requests for reimbursement of approximately $20.0 million pursuant to contractual indemnity provisions under the APA for various costs incurred. Calumet also asserted claims related to environmental matters. We rejected all of the currently pending claims for payment, and selected issues were arbitrated in July 2018. In September 2018, the arbitration panel ruled on the selected issues and held that the APA places a number of important limitations on claims advanced by Calumet. In a ruling dated August 16, 2019, as amended on October 3, 2019, the arbitration panel determined that, with regard to all claims asserted by Calumet, we do not owe any amounts to Calumet. Accordingly, during the third quarter of 2019, estimated costs previously accrued for this matter were reversed into income.

We filed a business interruption claim with our insurance carriers related to a fire at our Woods Cross Refinery that occurred in the first quarter 2018. As of SeptemberJune 30, 2019,2020, we have collected interim payments totaling $56.0 million, but have not reached a final agreement regarding the amounts owed to us pursuant to our business interruption coverage. We have accounted for this claim as a gain contingency and accordingly, we have deferred revenue recognition for the interim payments received until such time that uncertainties regarding the amounts owed to us have been resolved.

During 2017, 2018 and 2019, the EPA granted the Cheyenne Refinery and Woods Cross Refinery each a one-year small refinery exemption from the Renewable Fuel Standard (“RFS”) program requirements for the 2016, 2017 and 2018, respectively, calendar years. As a result, the Cheyenne Refinery’s and Woods Cross Refinery’s gasoline and diesel production are not subject to the Renewable Volume Obligation for the respective years. Upon each exemption granted, we increased our inventory of RINs and reduced our cost of products sold.

In 2019, various subsidiaries of HollyFrontier moved to intervene in four lawsuits brought by renewable fuel interest groups against the EPA in federal courts alleging violations of the RFS under the Clean Air Act and challenging the EPA’s handling of small refinery exemptions. We intervened to vigorously defend the EPA’s position on small refinery exemptions because we believe the EPA correctly applied applicable law to the matters at issue. The U.S. Court of Appeals for the DC Circuit dismissed one of these four lawsuits on November 12, 2019 for lack of jurisdiction. On January 24, 2020, the U.S. Court of Appeals for the Tenth Circuit vacated the small refinery exemptions granted to two of our refineries for 2016 and remanded the case to the EPA for further proceedings. On March 24, 2020, various subsidiaries of HollyFrontier filed a Petition for Rehearing with the U.S. Court of Appeals for the Tenth Circuit. On April 7, 2020, the Tenth Circuit denied our request to reconsider its decision, and on April 15, 2020, the Tenth Circuit entered its mandate, remanding the matter back to the EPA. It is not clear at this time what steps the EPA will take with respect to our 2016 small refinery exemptions, and we are unable to estimate the costs we may incur, if any, at this time. It is also not clear how the case will impact future small refinery exemptions. It is too early to assess whether the remaining two cases are expected to have any impact on us.


NOTE 17:15:Segment Information

Our operations are organized into 3 reportable segments, Refining, Lubricants and Specialty Products and HEP. Our operations that are not included in the Refining, Lubricants and Specialty Products and HEP segments are included in Corporate and Other. Intersegment transactions are eliminated in our consolidated financial statements and are included in Eliminations. Corporate and
Other and Eliminations are aggregated and presented under the Corporate, Other and Eliminations column.


The Refining segment represents the operations of the El Dorado, Tulsa, Navajo, Cheyenne and Woods Cross Refineries and HFC Asphalt (aggregated as a reportable segment). Refining activities involve the purchase and refining of crude oil and wholesale and branded marketing of refined products, such as gasoline, diesel fuel and jet fuel. These petroleum products are primarily marketed in the Mid-Continent, Southwest and Rocky Mountain regions of the United States. HFC Asphalt operates various asphalt terminals in Arizona, New Mexico and Oklahoma.

The Lubricants and Specialty Products segment involves PCLI’s production operations, located in Mississauga, Ontario, that includes lubricant products such as base oils, white oils, specialty products and finished lubricants, and the operations of our Petro- Canada Lubricants business that includes the marketing of products to both retail and wholesale outlets through a global sales network with locations in Canada, the United States, Europe and China. Additionally, the Lubricants and Specialty Products segment includes specialty lubricant products produced at our Tulsa Refineries that are marketed throughout North America and are distributed in Central and South America. Also, effective with our acquisition that closed August 1, 2018, the LubricantsAmerica and Specialty Products segment includes Red Giant Oil, one of the largest suppliers of locomotive engine oil in North America, andAmerica. Also, effective with our acquisition that closed February 1, 2019, the Lubricants and Specialty Products segment includes Sonneborn, a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes with manufacturing facilities in the United States and Europe.


The HEP segment includes all of the operations of HEP, which owns and operates logistics and refinery assets consisting of petroleum product and crude oil pipelines, terminals, tankage, loading rack facilities and refinery processing units in the Mid-Continent, Southwest and Rocky Mountain regions of the United States. As of SeptemberJune 30, 2019,2020, the HEP segment also includes a 75% ownership interest in UNEV (a consolidated subsidiary of HEP) and 50% ownership interests in each of the Osage Pipeline, and the Cheyenne Pipeline.Pipeline and Cushing Connect. Revenues from the HEP segment are earned through transactions with unaffiliated parties for pipeline transportation, rental and terminalling operations as well as revenues relating to pipeline transportation services provided for our refining operations. Due to certain basis differences, our reported amounts for the HEP segment may not agree to amounts reported in HEP’s periodic public filings.

The accounting policies for our segments are the same as those described in the summary of significant accounting policies in our Annual Report on Form 10-K for the year ended December 31, 20182019.
  Refining Lubricants and Specialty Products HEP 
Corporate, Other
and Eliminations
 
Consolidated
Total
  (In thousands)
Three Months Ended June 30, 2020        
Sales and other revenues:          
Revenues from external customers $1,690,042
 $353,644
 $19,244
 $—
 $2,062,930
Intersegment revenues 37,462
 3,643
 95,563
 (136,668) —
  $1,727,504
 $357,287
 $114,807
 $(136,668) $2,062,930
Cost of products sold (exclusive of lower of cost or market inventory) $1,433,437
 $258,347
 $—
 $(114,788) $1,576,996
Lower of cost or market inventory valuation adjustment $(269,904) $—
 $—
 $—
 $(269,904)
Operating expenses $239,359
 $47,840
 $34,737
 $(18,577) $303,359
Selling, general and administrative expenses $32,811
 $35,919
 $2,535
 $4,104
 $75,369
Depreciation and amortization $81,694
 $19,779
 $24,008
 $4,697
 $130,178
Long-lived asset impairment (1)
 $215,242
 $204,708
 $16,958
 $—
 $436,908
Income (loss) from operations $(5,135) $(209,306) $36,569
 $(12,104) $(189,976)
Earnings of equity method investments $—
 $—
 $2,156
 $—
 $2,156
Capital expenditures $12,102
 $4,311
 $11,798
 $17,776
 $45,987
           
Three Months Ended June 30, 2019        
Sales and other revenues:          
Revenues from external customers $4,208,776
 $545,346
 $28,382
 $111
 $4,782,615
Intersegment revenues 88,484
 —
 102,369
 (190,853) —
  $4,297,260
 $545,346
 $130,751
 $(190,742) $4,782,615
Cost of products sold (exclusive of lower of cost or market inventory) $3,458,832
 $415,353
 $—
 $(169,301) $3,704,884
Lower of cost or market inventory valuation adjustment $47,801
 $—
 $—
 $—
 $47,801
Operating expenses $252,715
 $59,122
 $40,608
 $(19,193) $333,252
Selling, general and administrative expenses $29,638
 $42,087
 $1,988
 $11,604
 $85,317
Depreciation and amortization $76,225
 $23,020
 $24,241
 $3,422
 $126,908
Goodwill impairment $—
 $152,712
 $—
 $—
 $152,712
Income (loss) from operations $432,049
 $(146,948) $63,914
 $(17,274) $331,741
Earnings of equity method investments $—
 $—
 $1,783
 $—
 $1,783
Capital expenditures $33,899
 $9,331
 $7,034
 $6,470
 $56,734


 Refining Lubricants and Specialty Products HEP 
Corporate, Other
and Eliminations
 
Consolidated
Total
 Refining Lubricants and Specialty Products HEP Corporate, Other
and Eliminations		 Consolidated
Total
 (In thousands) (In thousands)
Three Months Ended September 30, 2019        
Six Months Ended June 30, 2020Six Months Ended June 30, 2020        
Sales and other revenues:                    
Revenues from external customers $3,865,399
 $529,561
 $29,868
 $—
 $4,424,828
 $4,540,662
 $877,143
 $45,670
 $—
 $5,463,475
Intersegment revenues 81,571
 8,157
 106,027
 (195,755) —
 121,708
 6,747
 196,991
 (325,446) —
 $3,946,970
 $537,718
 $135,895
 $(195,755) $4,424,828
 $4,662,370
 $883,890
 $242,661
 $(325,446) $5,463,475
Cost of products sold (exclusive of lower of cost or market inventory) $3,177,167
 $397,926
 $—
 $(171,326) $3,403,767
 $3,902,188
 $649,727
 $—
 $(281,193) $4,270,722
Lower of cost or market inventory valuation adjustment $34,062
 $—
 $—
 $—
 $34,062
 $290,560
 $—
 $—
 $—
 $290,560
Operating expenses $276,869
 $57,974
 $44,924
 $(34,189) $345,578
 $498,533
 $101,971
 $69,718
 $(38,518) $631,704
Selling, general and administrative expenses $31,707
 $43,875
 $2,714
 $9,330
 $87,626
 $63,811
 $84,881
 $5,237
 $9,177
 $163,106
Depreciation and amortization $76,765
 $22,700
 $24,121
 $3,430
 $127,016
 $171,873
 $41,828
 $47,986
 $9,066
 $270,753
Long-lived asset impairment (1)
 $215,242
 $204,708
 $16,958
 $—
 $436,908
Income (loss) from operations $350,400
 $15,243
 $64,136
 $(3,000) $426,779
 $(479,837) $(199,225) $102,762
 $(23,978) $(600,278)
Earnings of equity method investments $—
 $—
 $1,334
 $—
 $1,334
 $—
 $—
 $3,870
 $—
 $3,870
Capital expenditures $53,506
 $8,697
 $6,076
 $6,310
 $74,589
 $65,116
 $13,392
 $30,740
 $20,488
 $129,736
                    
Three Months Ended September 30, 2018        
Six Months Ended June 30, 2019Six Months Ended June 30, 2019        
Sales and other revenues:                    
Revenues from external customers $4,270,835
 $474,260
 $25,596
 $108
 $4,770,799
 $7,581,442
 $1,038,680
 $59,520
 $220
 $8,679,862
Intersegment revenues 101,334
 1,626
 100,188
 (203,148) —
 163,228
 —
 205,728
 (368,956) —
 $4,372,169
 $475,886
 $125,784
 $(203,040) $4,770,799
 $7,744,670
 $1,038,680
 $265,248
 $(368,736) $8,679,862
Cost of products sold (exclusive of lower of cost or market inventory) $3,572,593
 $359,742
 $—
 $(180,101) $3,752,234
 $6,421,372
 $804,370
 $—
 $(321,653) $6,904,089
Lower of cost or market inventory valuation adjustment $17,837
 $—
 $—
 $—
 $17,837
 $(184,545) $—
 $—
 $—
 $(184,545)
Operating expenses $262,010
 $40,288
 $35,995
 $(21,097) $317,196
 $517,212
 $112,681
 $78,121
 $(43,170) $664,844
Selling, general and administrative expenses $30,394
 $33,514
 $2,498
 $4,724
 $71,130
 $56,615
 $81,806
 $4,608
 $30,322
 $173,351
Depreciation and amortization $70,793
 $11,139
 $24,367
 $2,586
 $108,885
 $150,640
 $43,191
 $48,071
 $6,427
 $248,329
Goodwill impairment $—
 $152,712
 $—
 $—
 $152,712
Income (loss) from operations $418,542
 $31,203
 $62,924
 $(9,152) $503,517
 $783,376
 $(156,080) $134,448
 $(40,662) $721,082
Earnings of equity method investments $—
 $—
 $1,114
 $—
 $1,114
 $—
 $—
 $3,883
 $—
 $3,883
Capital expenditures $47,088
 $8,094
 $9,541
 $5,214
 $69,937
 $75,662
 $17,190
 $17,752
 $9,865
 $120,469

(1) The results of our HEP reportable segment for the three and six months ended June 30, 2020 include a long-lived asset impairment charge attributed to HEP’s logistics assets at our Cheyenne Refinery.

  Refining Lubricants and Specialty Products HEP Corporate, Other
and Eliminations		 Consolidated
Total
  (In thousands)
Nine Months Ended September 30, 2019        
Sales and other revenues:          
Revenues from external customers $11,446,841
 $1,568,241
 $89,388
 $220
 $13,104,690
Intersegment revenues 244,799
 8,157
 311,755
 (564,711) —
  $11,691,640
 $1,576,398
 $401,143
 $(564,491) $13,104,690
Cost of products sold (exclusive of lower of cost or market inventory) $9,598,539
 $1,202,296
 $—
 $(492,979) $10,307,856
Lower of cost or market inventory valuation adjustment $(150,483) $—
 $—
 $—
 $(150,483)
Operating expenses $794,081
 $170,655
 $123,045
 $(77,359) $1,010,422
Selling, general and administrative expenses $88,322
 $125,681
 $7,322
 $39,652
 $260,977
Depreciation and amortization $227,405
 $65,891
 $72,192
 $9,857
 $375,345
Goodwill impairment $—
 $152,712
 $—
 $—
 $152,712
Income (loss) from operations $1,133,776
 $(140,837) $198,584
 $(43,662) $1,147,861
Earnings of equity method investments $—
 $—
 $5,217
 $—
 $5,217
Capital expenditures $129,167
 $25,887
 $23,828
 $16,175
 $195,057
           
Nine Months Ended September 30, 2018        
Sales and other revenues:          
Revenues from external customers $11,915,797
 $1,376,531
 $77,799
 $335
 $13,370,462
Intersegment revenues 284,538
 11,884
 295,629
 (592,051) —
  $12,200,335
 $1,388,415
 $373,428
 $(591,716) $13,370,462
Cost of products sold (exclusive of lower of cost or market inventory) $10,179,509
 $1,040,414
 $—
 $(524,648) $10,695,275
Lower of cost or market inventory valuation adjustment $(192,927) $—
 $—
 $—
 $(192,927)
Operating expenses $764,415
 $125,101
 $106,731
 $(62,548) $933,699
Selling, general and administrative expenses $82,966
 $99,425
 $8,293
 $13,785
 $204,469
Depreciation and amortization $210,957
 $30,023
 $74,117
 $8,508
 $323,605
Income (loss) from operations $1,155,415
 $93,452
 $184,287
 $(26,813) $1,406,341
Earnings of equity method investments $—
 $—
 $4,127
 $—
 $4,127
Capital expenditures $132,050
 $23,138
 $41,111
 $12,779
 $209,078
  Refining Lubricants and Specialty Products HEP 
Corporate, Other
and Eliminations
 
Consolidated
Total
  (In thousands)
June 30, 2020          
Cash and cash equivalents $15,652
 $189,571
 $18,913
 $678,373
 $902,509
Total assets $6,327,809
 $1,910,431
 $2,215,053
 $610,527
 $11,063,820
Long-term debt $—
 $—
 $1,486,648
 $994,098
 $2,480,746
           
December 31, 2019          
Cash and cash equivalents $9,755
 $169,277
 $13,287
 $692,843
 $885,162
Total assets $7,189,094
 $2,223,418
 $2,205,437
 $546,892
 $12,164,841
Long-term debt $—
 $—
 $1,462,031
 $993,609
 $2,455,640


  Refining Lubricants and Specialty Products HEP 
Corporate, Other
and Eliminations
 
Consolidated
Total
  (In thousands)
September 30, 2019          
Cash and cash equivalents $21,443
 $170,116
 $7,469
 $782,828
 $981,856
Total assets $7,321,741
 $2,139,092
 $2,089,110
 $641,385
 $12,191,328
Long-term debt $—
 $—
 $1,431,869
 $993,365
 $2,425,234
           
December 31, 2018          
Cash and cash equivalents $7,236
 $80,931
 $3,045
 $1,063,540
 $1,154,752
Total assets $6,465,155
 $1,506,209
 $2,142,027
 $881,210
 $10,994,601
Long-term debt $—
 $—
 $1,418,900
 $992,640
 $2,411,540



Table of Content


Item 2.Management’s Discussion and Analysis of Financial Condition and Results of Operations

This Item 2 contains “forward-looking” statements. See “Forward-Looking Statements” at the beginning of Part I of this Quarterly Report on Form 10-Q. References herein to HollyFrontier Corporation (“HollyFrontier”) include HollyFrontier and its consolidated subsidiaries. In accordance with the Securities and Exchange Commission’s (“SEC”) “Plain English” guidelines, this Quarterly Report on Form 10-Q has been written in the first person. In this document, the words “we,” “our,” “ours” and “us” refer only to HollyFrontier Corporation (“HollyFrontier”) and its consolidated subsidiaries or to HollyFrontier or an individual subsidiary and not to any other person with certain exceptions. Generally, the words “we,” “our,” “ours” and “us” include Holly Energy Partners, L.P. (“HEP”) and its subsidiaries as consolidated subsidiaries of HollyFrontier, unless when used in disclosures of transactions or obligations between HEP and HollyFrontier or its other subsidiaries. This document contains certain disclosures of agreements that are specific to HEP and its consolidated subsidiaries and do not necessarily represent obligations of HollyFrontier. When used in descriptions of agreements and transactions, “HEP” refers to HEP and its consolidated subsidiaries.


OVERVIEW

We are principally an independent petroleum refiner and marketer that produces high-value light products such as gasoline, diesel fuel, jet fuel, specialty lubricant products and other specialty products. We own and operatemodified asphalt. As of June 30, 2020, we owned and operated refineries located in El Dorado, Kansas (the “El Dorado Refinery”), Tulsa, Oklahoma (the “Tulsa Refineries”), which comprise two production facilities, the Tulsa West and East facilities, Artesia, New Mexico, which operates in conjunction with crude, vacuum distillation and other facilities situated 65 miles away in Lovington, New Mexico (collectively, the “Navajo Refinery”), Cheyenne, Wyoming (the “Cheyenne Refinery”) and Woods Cross, Utah (the “Woods Cross Refinery”). We market our refined products principally in the Southwest United States, the Rocky Mountains extending into the Pacific Northwest and in other neighboring Plains states. In addition, we produce base oils and other specialized lubricants in the United States, Canada and the Netherlands, and export products to more than 80 countries. We also own a 57% limited partner interest and a non-economic general partner interest in HEP, a master limited partnership that provides petroleum product and crude oil transportation, terminalling, storage and throughput services to the petroleum industry, including HollyFrontier Corporation subsidiaries.
On June 1, 2020, we announced plans to permanently cease petroleum refining operations at our Cheyenne Refinery and to convert certain assets at our Cheyenne Refinery to renewable diesel production. This decision was primarily based on a positive outlook on the market for renewable diesel and the expectation that future free cash flow generation at our Cheyenne Refinery would be challenged due to lower gross margins resulting from the economic impact of the COVID-19 pandemic and compressed crude differentials due to dislocations in the crude oil market. Additional factors included uncompetitive operating and maintenance costs forecasted for our Cheyenne Refinery and the anticipated loss of the Environmental Protection Agency’s (“EPA”) small refinery exemption. Approximately 200 employees at our Cheyenne Refinery are expected to be impacted by this decision. We began winding down refining operations at our Cheyenne Refinery on August 3, 2020, and subsequently began conversion of certain units for renewable diesel production. The renewable diesel units are expected to be completed in the first quarter of 2022 with an expected capital budget between $125-$175 million.

During the second quarter of 2020, we recorded a long-lived asset impairment of $232.2 million and accelerated depreciation of $2.2 million related to our Cheyenne Refinery asset groups. We expect to record additional non-cash charges of $3.7 million for accelerated depreciation in the third quarter of 2020.

Additionally, during the second quarter of 2020, we recorded $1.1 million in employee severance costs related to the conversion of our Cheyenne Refinery. Also, during the second quarter of 2020, we recorded a reserve of $6.2 million against our repair and maintenance supplies inventory. These severance costs and the inventory reserve charge were recognized in operating expenses and were reported in the Refining segment. Over the next twelve months, we anticipate pre-tax costs of approximately $45 million for decommissioning assets and $5-$7 million for severance obligations and proceeds of $50-$70 million from the liquidation of working capital. In addition, we may potentially incur further charges related to revisions in our estimates of asset retirement obligations for our Cheyenne Refinery.

During the second quarter of 2020, we initiated and completed a corporate restructuring, which is expected to save approximately $30 million per year of ongoing cash expenses. As a result of this restructuring, we recorded $3.7 million in employee severance costs, which were recognized primarily as operating expenses in our Refining segment and selling, general and administrative expenses in our Corporate and Other segment.

On November 12, 2018, we entered into an equity purchase agreement to acquire 100% of the issued and outstanding capital stock of Sonneborn US Holdings Inc. and 100% of the membership rights in Sonneborn Coöperatief U.A. (collectively, “Sonneborn”). The acquisition closed on February 1, 2019. Cash consideration paid was $662.7 million. Sonneborn is a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes with manufacturing facilities in the United States and Europe.

On July 10, 2018, we entered into a definitive agreement to acquire Red Giant Oil Company LLC (“Red Giant Oil”), a privately-owned lubricants company. The acquisition closed on August 1, 2018. Cash consideration paid was $54.2 million. Red Giant Oil is one
Table of the largest suppliers of locomotive engine oil in North America and is headquartered in Council Bluffs, Iowa with storage and distribution facilities in Iowa, Kansas, Utah and Wyoming, along with a blending and packaging facility in Texas.Content

For the three months ended SeptemberJune 30, 2019,2020, net incomeloss attributable to HollyFrontier stockholders was $261.8$(176.7) million compared to $342.5net income of $196.9 million for the three months ended SeptemberJune 30, 2018.2019. For the ninesix months ended SeptemberJune 30, 2019,2020, net incomeloss attributable to HollyFrontier stockholders was $711.8$(481.3) million compared to $956.1net income of $450.0 million for the ninesix months ended SeptemberJune 30, 2018. Overall gross refining margins per produced barrel sold for the three months ended September 30, 2019 decreased 11% over the same period of 2018 due to a decrease in the average per barrel sold sales price during the current year quarter, partially offset by decreased crude oil and feedstock prices.2019. Included in our financial results for the thirdsecond quarter wasof 2020 were non-cash items consisting of $436.9 million long-lived asset impairment charges related to our Cheyenne Refinery and PCLI, offset by an inventory reserve adjustment that decreased pre-taxresulted in a benefit of $269.9 million. Second quarter earnings by $34.1 million.reflect weak demand for refined products, lubricants and transportation services across the industry, with overall gross refining margin per produced barrel sold decreasing 57% for the three months ended June 30, 2020 over the same period of 2019. Included in the three months ended June 30, 2019, was a goodwill impairment charge of $152.7 million related to our Lubricants and Specialty Products segment.

Pursuant to the 2007 Energy Independence and Security Act, the Environmental Protection Agency (“EPA”)EPA promulgated the Renewable Fuel Standard (“RFS”) regulations, which increased the volume of renewable fuels mandated to be blended into the nation’s fuel supply. The regulations, in part, require refiners to add annually increasing amounts of “renewable fuels” to their petroleum products or purchase credits, known as renewable identification numbers (“RINs”), in lieu of such blending. Compliance with RFS regulations significantly increases our cost of products sold, with RINs costs totaling $8.4$32.5 million for the three months ended SeptemberJune 30, 2019, which is net2020.

Impact of COVID-19 on Our Business
The COVID-19 pandemic caused a decline in U.S. and global economic activity starting in the first quarter of 2020. This decrease reduced both volumes and unit margins across our businesses, resulting in lower gross margins and earnings. Over the course of the $36.6 million cost reduction resulting from small refinery RINs waivers granted by the EPA in 2019 as described in Note 9 “Inventories”second quarter, demand for transportation fuels and lubricants stabilized and showed incremental improvement late in the Notesquarter. In response to Consolidated Financial Statements.this level of demand, during the second quarter of 2020, we operated our Refining segment refineries at an average crude charge of 349,580 BPD.

The stabilization of demand drove a broad increase in commodity prices, resulting in values for our inventories held at June 30, 2020 above the costs of these inventories using the last-in, first-out (“LIFO”) method and in a lower of cost or market valuation gain of $269.9 million for the three months ended June 30, 2020. Additionally, this stabilization of demand and commodity prices resulted in a smaller than expected use of working capital during the quarter.

As a result of these conditions, we have reduced our 2020 expected total consolidated capital expenditures by approximately 15%, to a range of $525 million to $625 million. Additionally, during the second quarter, we completed a corporate restructuring program expected to save approximately $30 million per year in ongoing cash expenses.

HollyFrontier’s standalone (excluding HEP) liquidity was over $2.2 billion at June 30, 2020, consisting of a cash balance of $883.6 million and an undrawn $1.35 billion credit facility maturing in 2022. HollyFrontier’s earliest standalone (excluding HEP) debt maturity is $1.0 billion of senior notes due in 2026.


OUTLOOK

The impact of COVID-19 on the global macroeconomy has created unprecedented reduction in demand, as well as lack of forward visibility, for many of the transportation fuels, lubricants and specialty products and the associated transportation and terminal services we provide. Other factors expected to impact crude oil supply include production levels implemented by OPEC members, other large oil producers such as Russia and domestic and Canadian oil producers. While we have seen a recent stabilization in demand and commodity and expect a strong recovery of demand for all of these essential products in the long-run, there remains little visibility on the timing for or extent of this recovery in the near term.

In response to the COVID-19 pandemic, and with the health and safety of our employees as a top priority, we have continued several initiatives, including limiting onsite staff at all of our facilities to essential operational personnel only, using a work from home policy for certain employees and restricting travel unless approved by senior leadership. We will continue to monitor COVID-19 developments and the dynamic environment to properly address these policies going forward.

Within our Refining segment, for the third quarter 2020, we expect to run between 340,000-370,000 barrels per day of crude oil based on market demand for transportation fuels. Currently, the primary determinants of demand are the various government orders and guidance restricting or discouraging most forms of travel. We expect to adjust refinery production levels commensurate with market demand.

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OUTLOOK

For the fourth quarter of 2019, we expect crack spreads to experience typical seasonal weakness as demand for refined products softens. Operationally, we are currently undergoing turnarounds at our El Dorado and Cheyenne refineries, and we expect to run between 380,000 to 390,000 barrels per day of crude oil.

In our Lubricants and Specialty Products segment, we expecthave withdrawn 2020 guidance for the Rack Forward businessbusiness. Within our industrial and passenger car-related end markets, demand saw improvement over the course of the second quarter as compared to perform well based on steadythe depressed levels we saw at the end of the first quarter of 2020, while in our personal care end markets, demand for finished products.continues to run slightly below historical levels. We expect thisindustrial demand to be offset somewhat by oversupply incontinue to rebound with the broader economy. Within the Rack Back portion, we expect base oil markets which will depress Rack Back earnings indemand to rebound with the fourth quarter.reopening of its primary transportation-related end markets. Similar to our Refining segment, we intend to match production to market demand.

At HEP, we anticipate typical seasonal strengtheninghave seen an improvement in demand for transportation and terminal services during the second quarter of 2020 as compared to the first quarter of 2020, and we expect that trend to continue. HEP maintained its quarterly distribution to $0.35 per unit, representative of a new distribution policy focused on funding all capital expenditures and distributions within cash flow, improving distributable cash flow coverage to 1.3x or greater and reducing leverage to 3.0-3.5x.

During the quarter, we announced plans to further expand our renewables business through the construction of a pre-treatment unit located at the Navajo Refinery’s Artesia facility and conversion of the Cheyenne Refinery to renewable diesel production. Including this decision, we maintained the range of our 2020 consolidated capital budget at $525 million to $625 million. Additionally, we implemented a corporate restructuring program expected to save approximately $30 million of annual expenses. We continue to evaluate additional ways to reduce cash costs including operating, sales, general and administrative spending reductions as well as incremental capital spending reductions. We do not intend to repurchase common stock under our $1.0 billion share repurchase program until commodity prices and demand for our products normalize.

On March 27, 2020, the U.S. government passed the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”), an approximately $2 trillion stimulus package that includes various provisions intended to provide relief to individuals and businesses in the fourth quarter aroundform of tax changes, loans and grants, among others. At this time, we have not sought relief in the UNEV pipelineform of loans or grants from the CARES Act; however, we have benefited from certain tax deferrals in the CARES Act and may benefit from other tax provisions if we meet the requirements to drive higher sequential earnings. Fordo so.

The extent to which our future results are affected by COVID-19 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. COVID-19, 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, 2019 and through 2020, HEP expectsin this Form 10-Q. COVID-19 may also materially adversely affect our results in a manner that is either not currently known or that we do not currently consider to hold the quarterly distribution constant at $0.6725 per unit, or $2.69be a significant risk to our business.

See “Item 1A - Risk Factors” for other potential impacts of COVID-19 on an annualized basis, while maintaining a distribution coverage ratio of 1.0x. HEP’s 2020 distribution guidance reflects growth from contractual tariff escalators and the recently announced Cushing Connect joint venture, offset by lower revenues from Delek and elevated maintenance capital expenditures due to one-time events.our business.

A more detailed discussion of our financial and operating results for the three and ninesix months ended SeptemberJune 30, 20192020 and 20182019 is presented in the following sections.

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RESULTS OF OPERATIONS

Financial Data
 Three Months Ended
September 30,		 Change from 2018 Three Months Ended June 30, Change from 2019
 2019 2018 Change Percent 2020 2019 Change Percent
 (In thousands, except per share data) (In thousands, except per share data)
Sales and other revenues $4,424,828
 $4,770,799
 $(345,971) (7)% $2,062,930
 $4,782,615
 $(2,719,685) (57)%
Operating costs and expenses:                
Cost of products sold (exclusive of depreciation and amortization):                
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) 3,403,767
 3,752,234
 (348,467) (9) 1,576,996
 3,704,884
 (2,127,888) (57)
Lower of cost or market inventory valuation adjustment 34,062
 17,837
 16,225
 91
 (269,904) 47,801
 (317,705) (665)
 3,437,829
 3,770,071
 (332,242) (9) 1,307,092
 3,752,685
 (2,445,593) (65)
Operating expenses (exclusive of depreciation and amortization) 345,578
 317,196
 28,382
 9
 303,359
 333,252
 (29,893) (9)
Selling, general and administrative expenses (exclusive of depreciation and amortization) 87,626
 71,130
 16,496
 23
 75,369
 85,317
 (9,948) (12)
Depreciation and amortization 127,016
 108,885
 18,131
 17
 130,178
 126,908
 3,270
 3
Long-lived asset and goodwill impairments 436,908
 152,712
 284,196
 186
Total operating costs and expenses 3,998,049
 4,267,282
 (269,233) (6) 2,252,906
 4,450,874
 (2,197,968) (49)
Income from operations 426,779
 503,517
 (76,738) (15)
Income (loss) from operations (189,976) 331,741
 (521,717) (157)
Other income (expense):                
Earnings of equity method investments 1,334
 1,114
 220
 20
 2,156
 1,783
 373
 21
Interest income 6,164
 5,136
 1,028
 20
 1,506
 4,588
 (3,082) (67)
Interest expense (36,027) (32,399) (3,628) 11
 (32,695) (34,264) 1,569
 (5)
Gain on sales-type leases 33,834
 —
 33,834
 —
Gain on foreign currency transactions 395
 281
 114
 41
 2,285
 2,213
 72
 3
Other, net 2,356
 741
 1,615
 218
 1,572
 92
 1,480
 1,609
 (25,778) (25,127) (651) 3
 8,658
 (25,588) 34,246
 (134)
Income before income taxes 401,001
 478,390
 (77,389) (16)
Income tax expense 103,021
 116,258
 (13,237) (11)
Net income 297,980
 362,132
 (64,152) (18)
Income (loss) before income taxes (181,318) 306,153
 (487,471) (159)
Income tax expense (benefit) (30,911) 89,336
 (120,247) (135)
Net income (loss) (150,407) 216,817
 (367,224) (169)
Less net income attributable to noncontrolling interest 36,167
 19,666
 16,501
 84
 26,270
 19,902
 6,368
 32
Net income attributable to HollyFrontier stockholders $261,813
 $342,466
 $(80,653) (24)%
Earnings per share attributable to HollyFrontier stockholders:        
Net income (loss) attributable to HollyFrontier stockholders $(176,677) $196,915
 $(373,592) (190)%
Earnings (loss) per share attributable to HollyFrontier stockholders:        
Basic $1.60
 $1.95
 $(0.35) (18)% $(1.09) $1.16
 $(2.25) (194)%
Diluted $1.58
 $1.93
 $(0.35) (18)% $(1.09) $1.15
 $(2.24) (195)%
Cash dividends declared per common share $0.33
 $0.33
 $—
 — % $0.35
 $0.33
 $0.02
 6 %
Average number of common shares outstanding:                
Basic 163,676
 175,097
 (11,421) (7)% 161,889
 169,356
 (7,467) (4)%
Diluted 165,011
 176,927
 (11,916) (7)% 161,889
 170,547
 (8,658) (5)%

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 Nine Months Ended
September 30,		 Change from 2018 Six Months Ended June 30, Change from 2019
 2019 2018 Change Percent 2020 2019 Change Percent
 (In thousands, except per share data) (In thousands, except per share data)
Sales and other revenues $13,104,690
 $13,370,462
 $(265,772) (2)% $5,463,475
 $8,679,862
 $(3,216,387) (37)%
Operating costs and expenses:                
Cost of products sold (exclusive of depreciation and amortization):                
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) 10,307,856
 10,695,275
 (387,419) (4) 4,270,722
 6,904,089
 (2,633,367) (38)
Lower of cost or market inventory valuation adjustment (150,483) (192,927) 42,444
 (22) 290,560
 (184,545) 475,105
 (257)
 10,157,373
 10,502,348
 (344,975) (3) 4,561,282
 6,719,544
 (2,158,262) (32)
Operating expenses (exclusive of depreciation and amortization) 1,010,422
 933,699
 76,723
 8
 631,704
 664,844
 (33,140) (5)
Selling, general and administrative expenses (exclusive of depreciation and amortization) 260,977
 204,469
 56,508
 28
 163,106
 173,351
 (10,245) (6)
Depreciation and amortization 375,345
 323,605
 51,740
 16
 270,753
 248,329
 22,424
 9
Goodwill impairment 152,712
 —
 152,712
 —
Long-lived asset and goodwill impairments 436,908
 152,712
 284,196
 186
Total operating costs and expenses 11,956,829
 11,964,121
 (7,292) —
 6,063,753
 7,958,780
 (1,895,027) (24)
Income from operations 1,147,861
 1,406,341
 (258,480) (18)
Income (loss) from operations (600,278) 721,082
 (1,321,360) (183)
Other income (expense):                
Earnings of equity method investments 5,217
 4,127
 1,090
 26
 3,870
 3,883
 (13) —
Interest income 17,127
 10,660
 6,467
 61
 5,579
 10,963
 (5,384) (49)
Interest expense (106,938) (97,446) (9,492) 10
 (55,334) (70,911) 15,577
 (22)
Gain on foreign currency transactions 4,873
 5,516
 (643) (12)
Gain on sales-type leases 33,834
 —
 33,834
 —
Loss on early extinguishment of debt (25,915) —
 (25,915) —
Gain (loss) on foreign currency transactions (1,948) 4,478
 (6,426) (144)
Other, net 3,005
 3,451
 (446) (13) 3,422
 649
 2,773
 427
 (76,716) (73,692) (3,024) 4
 (36,492) (50,938) 14,446
 (28)
Income before income taxes 1,071,145
 1,332,649
 (261,504) (20)
Income tax expense 279,862
 318,742
 (38,880) (12)
Net income 791,283
 1,013,907
 (222,624) (22)
Income (loss) before income taxes (636,770) 670,144
 (1,306,914) (195)
Income tax expense (benefit) (193,077) 176,841
 (369,918) (209)
Net income (loss) (443,693) 493,303
 (936,996) (190)
Less net income attributable to noncontrolling interest 79,500
 57,843
 21,657
 37
 37,607
 43,333
 (5,726) (13)
Net income attributable to HollyFrontier stockholders $711,783
 $956,064
 $(244,281) (26)%
Earnings per share attributable to HollyFrontier stockholders:        
Net income (loss) attributable to HollyFrontier stockholders $(481,300) $449,970
 $(931,270) (207)%
Earnings (loss) per share attributable to HollyFrontier stockholders:        
Basic $4.23
 $5.42
 $(1.19) (22)% $(2.97) $2.64
 $(5.61) (213)%
Diluted $4.20
 $5.37
 $(1.17) (22)% $(2.97) $2.62
 $(5.59) (213)%
Cash dividends declared per common share $0.99
 $0.99
 $—
 — % $0.70
 $0.66
 $0.04
 6 %
Average number of common shares outstanding:                
Basic 167,935
 175,865
 (7,930) (5)% 161,882
 170,100
 (8,218) (5)%
Diluted 169,125
 177,557
 (8,432) (5)% 161,882
 171,264
 (9,382) (5)%


Balance Sheet Data
 September 30, 2019 December 31, 2018 June 30, 2020 December 31, 2019
 (Unaudited)   (Unaudited)  
 (In thousands) (In thousands)
Cash and cash equivalents $981,856
 $1,154,752
 $902,509
 $885,162
Working capital $1,827,420
 $2,128,224
 $1,470,492
 $1,620,261
Total assets $12,191,328
 $10,994,601
 $11,063,820
 $12,164,841
Long-term debt $2,425,234
 $2,411,540
 $2,480,746
 $2,455,640
Total equity $6,541,363
 $6,459,059
 $5,914,511
 $6,509,426

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Other Financial Data 
 Three Months Ended September 30, Nine Months Ended September 30, Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
 (In thousands) (In thousands)
Net cash provided by operating activities $441,854
 $401,752
 $1,411,404
 $1,129,897
 $119,204
 $752,734
 $309,302
 $969,550
Net cash used for investing activities $(74,455) $(113,089) $(856,764) $(259,167) $(45,572) $(55,584) $(131,666) $(782,309)
Net cash used for financing activities $(299,473) $(193,701) $(729,337) $(423,416) $(84,062) $(279,736) $(155,519) $(429,864)
Capital expenditures $74,588
 $69,937
 $195,057
 $209,078
 $45,987
 $56,734
 $129,736
 $120,469
EBITDA (1)
 $521,713
 $594,872
 $1,456,801
 $1,685,197
 $(46,221) $442,835
 $(353,869) $935,088

(1)Earnings before interest, taxes, depreciation and amortization, which we refer to as “EBITDA,” is calculated as net income (loss) attributable to HollyFrontier stockholders plus (i) interest expense, net of interest income, (ii) income tax provision, and (iii) depreciation and amortization. EBITDA is not a calculation provided for under GAAP; however, the amounts included in the EBITDA calculation are derived from amounts included in our consolidated financial statements. EBITDA should not be considered as an alternative to net income or operating income as an indication of our operating performance or as an alternative to operating cash flow as a measure of liquidity. EBITDA is not necessarily comparable to similarly titled measures of other companies. EBITDA is presented here because it is a widely used financial indicator used by investors and analysts to measure performance. EBITDA is also used by our management for internal analysis and as a basis for financial covenants. EBITDA presented above is reconciled to net income under “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q.

Segment Operating Data

Our operations are organized into three reportable segments, Refining, Lubricants and Specialty Products and HEP. See Note 1715 “Segment Information” in the Notes to Consolidated Financial Statements for additional information on our reportable segments.

Refining Segment Operating Data

Our refinery operations include the El Dorado, Tulsa, Navajo, Cheyenne and Woods Cross Refineries. The following tables set forth information, including non-GAAP performance measures, about our consolidated refinery operations. The cost of products and refinery gross and net operating margins do not include the non-cash effects of long-lived asset impairment charges, lower of cost or market inventory valuation adjustments and depreciation and amortization. Reconciliations to amounts reported under GAAP are provided under “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q. 

 Three Months Ended September 30, Nine Months Ended September 30, Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
Mid-Continent Region (El Dorado and Tulsa Refineries)        Mid-Continent Region (El Dorado and Tulsa Refineries)      
Crude charge (BPD) (1)
 294,380
 262,550
 257,590
 260,150
 206,950
 264,290
 229,670
 238,890
Refinery throughput (BPD) (2)
 307,720
 276,560
 272,440
 274,330
 220,010
 278,710
 245,470
 254,520
Sales of produced refined products (BPD) (3)
 290,930
 255,840
 260,780
 259,890
 216,280
 273,010
 237,760
 245,450
Refinery utilization (4)
 113.2% 101.0% 99.1% 100.1% 79.6% 101.7% 88.3% 91.9%
                
Average per produced barrel (5)
                
Refinery gross margin $14.61
 $16.43
 $14.55
 $12.99
 $6.31
 $17.17
 $8.07
 $14.51
Refinery operating expenses (6)
 5.05
 5.48
 5.48
 5.18
 5.68
 5.02
 5.47
 5.74
Net operating margin $9.56
 $10.95
 $9.07
 $7.81
 $0.63
 $12.15
 $2.60
 $8.77
                
Refinery operating expenses per throughput barrel (7)
 $4.77
 $5.07
 $5.25
 $4.90
 $5.58
 $4.92
 $5.30
 $5.54
                
Feedstocks:                
Sweet crude oil 59% 59% 56% 54% 61% 57% 56% 54%
Sour crude oil 21% 21% 23% 24% 16% 22% 19% 23%
Heavy sour crude oil 16% 15% 16% 17% 17% 16% 19% 17%
Other feedstocks and blends 4% 5% 5% 5% 6% 5% 6% 6%
Total 100% 100% 100% 100% 100% 100% 100% 100%
Table of Content

 Three Months Ended September 30, Nine Months Ended September 30, Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
Mid-Continent Region (El Dorado and Tulsa Refineries)                
Sales of produced refined products:                
Gasolines 49% 49% 51% 51% 54% 51% 53% 52%
Diesel fuels 34% 34% 32% 33% 36% 34% 33% 31%
Jet fuels 6% 6% 7% 6% 1% 6% 4% 7%
Fuel oil 1% 1% 1% 1% 1% 1% 1% 1%
Asphalt 4% 4% 3% 3% 3% 2% 3% 3%
Base oils 4% 4% 4% 4% 3% 4% 4% 4%
LPG and other 2% 2% 2% 2% 2% 2% 2% 2%
Total 100% 100% 100% 100% 100% 100% 100% 100%
Southwest Region (Navajo Refinery)                
Crude charge (BPD) (1)
 106,860
 109,560
 107,330
 109,200
 79,460
 109,080
 93,130
 107,560
Refinery throughput (BPD) (2)
 117,250
 117,880
 117,660
 118,300
 89,470
 119,480
 103,460
 117,860
Sales of produced refined products (BPD) (3)
 116,890
 122,210
 120,760
 120,900
 101,880
 122,090
 107,740
 122,730
Refinery utilization (4)
 106.9% 109.6% 107.3% 109.2% 79.5% 109.1% 93.1% 107.6%
                
Average per produced barrel (5)
                
Refinery gross margin $18.61
 $22.60
 $19.35
 $17.84
 $11.08
 $23.45
 $11.89
 $19.70
Refinery operating expenses (6)
 5.25
 4.53
 4.90
 4.63
 5.12
 4.53
 5.20
 4.73
Net operating margin $13.36
 $18.07
 $14.45
 $13.21
 $5.96
 $18.92
 $6.69
 $14.97
                
Refinery operating expenses per throughput barrel (7)
 $5.23
 $4.69
 $5.03
 $4.73
 $5.83
 $4.63
 $5.42
 $4.93
                
Feedstocks:                
Sweet crude oil 22% 28% 21% 31% 25% 24% 24% 20%
Sour crude oil 69% 65% 70% 61% 64% 67% 66% 71%
Other feedstocks and blends 9% 7% 9% 8% 11% 9% 10% 9%
Total 100% 100% 100% 100% 100% 100% 100% 100%
                
Sales of produced refined products:                
Gasolines 50% 49% 51% 50% 53% 48% 54% 51%
Diesel fuels 40% 41% 39% 40% 34% 40% 36% 38%
Fuel oil 3% 3% 3% 3% 2% 4% 2% 3%
Asphalt 5% 5% 5% 4% 8% 6% 5% 5%
LPG and other 2% 2% 2% 3% 3% 2% 3% 3%
Total 100% 100% 100% 100% 100% 100% 100% 100%
Rocky Mountain Region (Cheyenne and Woods Cross Refineries)        Rocky Mountain Region (Cheyenne and Woods Cross Refineries)      
Crude charge (BPD) (1)
 74,790
 69,880
 78,530
 71,000
 63,170
 79,660
 70,170
 80,440
Refinery throughput (BPD) (2)
 81,830
 76,120
 85,300
 78,410
 68,020
 86,700
 75,610
 87,080
Sales of produced refined products (BPD) (3)
 77,680
 69,720
 77,890
 74,850
 64,750
 74,000
 72,100
 78,000
Refinery utilization (4)
 77.1% 72.0% 81.0% 73.2% 65.1% 82.1% 72.3% 82.9%
                
Average per produced barrel (6)(5)
                
Refinery gross margin (8)
 $24.97
 $24.75
 $19.73
 $24.95
 $11.41
 $22.48
 $13.54
 $17.07
Refinery operating expenses (9)(6)
 11.95
 12.80
 11.39
 11.97
 13.60
 11.53
 12.17
 11.11
Net operating margin (8)
 $13.02
 $11.95
 $8.34
 $12.98
 $(2.19) $10.95
 $1.37
 $5.96
                
Refinery operating expenses per throughput barrel (10)
 $11.34
 $11.72
 $10.40
 $11.42
Refinery operating expenses per throughput barrel (7)
 $12.95
 $9.84
 $11.61
 $9.95
Table of Content

 Three Months Ended September 30, Nine Months Ended September 30, Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
Rocky Mountain Region (Cheyenne and Woods Cross Refineries)        Rocky Mountain Region (Cheyenne and Woods Cross Refineries)      
Feedstocks:                
Sweet crude oil 38% 24% 36% 25% 37% 34% 36% 35%
Heavy sour crude oil 30% 44% 33% 44% 41% 35% 38% 35%
Black wax crude oil 23% 24% 23% 22% 15% 23% 19% 22%
Other feedstocks and blends 9% 8% 8% 9% 7% 8% 7% 8%
Total 100% 100% 100% 100% 100% 100% 100% 100%
                
Sales of produced refined products:                
Gasolines 54% 54% 53% 56% 54% 50% 55% 52%
Diesel fuels 32% 34% 34% 33% 35% 37% 33% 35%
Fuel oil 4% 2% 4% 3% 2% 4% 3% 4%
Asphalt 5% 7% 5% 5% 6% 6% 6% 6%
LPG and other 5% 3% 4% 3% 3% 3% 3% 3%
Total 100% 100% 100% 100% 100% 100% 100% 100%
Consolidated                
Crude charge (BPD) (1)
 476,030
 441,990
 443,450
 440,350
 349,580
 453,030
 392,970
 426,890
Refinery throughput (BPD) (2)
 506,800
 470,560
 475,400
 471,040
 377,500
 484,890
 424,540
 459,460
Sales of produced refined products (BPD) (3)
 485,500
 447,770
 459,440
 455,640
 382,910
 469,100
 417,600
 446,190
Refinery utilization (4)
 104.2% 96.7% 97.0% 96.4% 76.5% 99.1% 86.0% 93.4%
                
Average per produced barrel (5)
                
Refinery gross margin $17.23
 $19.41
 $16.69
 $16.25
 $8.44
 $19.64
 $10.00
 $16.39
Refinery operating expenses (6)
 6.20
 6.36
 6.33
 6.15
 6.87
 5.92
 6.56
 6.40
Net operating margin $11.03
 $13.05
 $10.36
 $10.10
 $1.57
 $13.72
 $3.44
 $9.99
                
Refinery operating expenses per throughput barrel (7)
 $5.94
 $6.05
 $6.12
 $5.94
 $6.97
 $5.73
 $6.45
 $6.22
                
Feedstocks:                
Sweet crude oil 47% 45% 44% 43% 48% 44% 45% 42%
Sour crude oil 29% 29% 30% 30% 25% 29% 27% 31%
Heavy sour crude oil 14% 16% 15% 17% 17% 16% 17% 16%
Black wax crude oil 4% 4% 4% 4% 3% 4% 4% 4%
Other feedstocks and blends 6% 6% 7% 6% 7% 7% 7% 7%
Total 100% 100% 100% 100% 100% 100% 100% 100%
Sales of produced refined products:                
Gasolines 50% 50% 51% 52% 54% 50% 53% 52%
Diesel fuels 35% 36% 35% 35% 35% 36% 34% 34%
Jet fuels 4% 3% 4% 3% 1% 4% 3% 4%
Fuel oil 2% 2% 2% 2% 1% 2% 1% 2%
Asphalt 4% 5% 4% 4% 4% 4% 4% 4%
Base oils 2% 2% 2% 2% 2% 2% 2% 2%
LPG and other 3% 2% 2% 2% 3% 2% 3% 2%
Total 100% 100% 100% 100% 100% 100% 100% 100%
 
(1)Crude charge represents the barrels per day of crude oil processed at our refineries.
(2)Refinery throughput represents the barrels per day of crude and other refinery feedstocks input to the crude units and other conversion units at our refineries.
(3)Represents barrels sold of refined products produced at our refineries (including HFC Asphalt) and does not include volumes
of refined products purchased for resale or volumes of excess crude oil sold.
(4)Represents crude charge divided by total crude capacity (BPSD). Our consolidated crude capacity is 457,000 BPSD.
(5)Represents average amount per produced barrel sold, which is a non-GAAP measure. Reconciliations to amounts reported under GAAP are provided under “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q.
Table of Content

(6)Represents total refining segment operating expenses, exclusive of depreciation and amortization, divided by sales volumes
of refined products produced at our refineries.
(7)Represents total refining segment operating expenses, exclusive of depreciation and amortization, divided by refinery throughput.

Lubricants and Specialty Products Operating Data

The following table sets forth information about our lubricants and specialty products operations. For the six months ended June 30, 2019, our lubricants and specialty products operating results reflect the operations of our Sonneborn business for the period February 1, 2019 (date of acquisition) through June 30, 2019.
 Three Months Ended September 30, Nine Months Ended September 30, Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
Lubricants and Specialty Products                
Throughput (BPD) 23,190
 21,410
 19,920
 20,530
 16,370
 16,990
 19,060
 18,390
Sales of produced refined products (BPD) 36,160
 31,970
 34,740
 21,340
 26,990
 34,660
 31,900
 34,050
                
Sales of produced refined products:                
Finished products 50% 49% 50% 48% 56% 52% 51% 50%
Base oils 24% 28% 27% 31% 19% 32% 23% 29%
Other 26% 23% 23% 21% 25% 16% 26% 21%
Total 100% 100% 100% 100% 100% 100% 100% 100%

Supplemental financial data attributable to our Lubricants and Specialty Products segment is presented below.
 
Rack Back (1)
 
Rack Forward (2)
 
Eliminations (3)
 Total Lubricants and Specialty Products 
Rack Back (1)
 
Rack Forward (2)
 
Eliminations (3)
 Total Lubricants and Specialty Products
 (In thousands) (In thousands)
Three months ended September 30, 2019        
Three months ended June 30, 2020        
Sales and other revenues $196,355
 $477,261
 $(135,898) $537,718
 $85,857
 $343,927
 $(72,497) $357,287
Cost of products sold $175,976
 $357,848
 $(135,898) $397,926
 $67,210
 $263,634
 $(72,497) $258,347
Operating expenses $27,825
 $30,149
 $—
 $57,974
 $21,034
 $26,806
 $—
 $47,840
Selling, general and administrative expenses $5,862
 $38,013
 $—
 $43,875
 $5,617
 $30,302
 $—
 $35,919
Depreciation and amortization $11,390
 $11,310
 $—
 $22,700
 $5,877
 $13,902
 $—
 $19,779
Long-lived asset impairment $167,017
 $37,691
 $—
 $204,708
Income (loss) from operations $(24,698) $39,941
 $—
 $15,243
 $(180,898) $(28,408) $—
 $(209,306)
                
Three months ended September 30, 2018        
Three months ended June 30, 2019        
Sales and other revenues $197,226
 $424,386
 $(145,726) $475,886
 $133,225
 $507,183
 $(95,062) $545,346
Cost of products sold $177,748
 $327,720
 $(145,726) $359,742
 $131,725
 $378,690
 $(95,062) $415,353
Operating expenses $26,748
 $13,540
 $—
 $40,288
 $30,585
 $28,537
 $—
 $59,122
Selling, general and administrative expenses $7,439
 $26,075
 $—
 $33,514
 $6,366
 $35,721
 $—
 $42,087
Depreciation and amortization $6,345
 $4,794
 $—
 $11,139
 $11,075
 $11,945
 $—
 $23,020
Goodwill impairment (4)
 $152,712
 $—
 $—
 $152,712
Income (loss) from operations $(21,054) $52,257
 $—
 $31,203
 $(199,238) $52,290
 $—
 $(146,948)
Table of Content



 
Rack Back (1)
 
Rack Forward (2)
 
Eliminations (3)
 Total Lubricants and Specialty Products 
Rack Back (1)
 
Rack Forward (2)
 
Eliminations (3)
 Total Lubricants and Specialty Products
 (In thousands) (In thousands)
Nine months ended September 30, 2019        
Six months ended June 30, 2020        
Sales and other revenues $250,686
 $817,984
 $(184,780) $883,890
Cost of products sold $247,810
 $586,697
 $(184,780) $649,727
Operating expenses $44,303
 $57,668
 $—
 $101,971
Selling, general and administrative expenses $10,980
 $73,901
 $—
 $84,881
Depreciation and amortization $16,744
 $25,084
 $—
 $41,828
Long-lived asset impairment $167,017
 $37,691
 $—
 $204,708
Income (loss) from operations $(236,168) $36,943
 $—
 $(199,225)
        
Six months ended June 30, 2019        
Sales and other revenues $486,035
 $1,428,786
 $(338,423) $1,576,398
 $289,680
 $951,525
 $(202,525) $1,038,680
Cost of products sold $453,519
 $1,087,200
 $(338,423) $1,202,296
 $277,543
 $729,352
 $(202,525) $804,370
Operating expenses $87,970
 $82,685
 $—
 $170,655
 $60,145
 $52,536
 $—
 $112,681
Selling, general and administrative expenses $25,707
 $99,974
 $—
 $125,681
 $19,845
 $61,961
 $—
 $81,806
Depreciation and amortization $32,991
 $32,900
 $—
 $65,891
 $21,601
 $21,590
 $—
 $43,191
Goodwill impairment (4)
 $152,712
 $—
 $—
 $152,712
 $152,712
 $—
 $—
 $152,712
Income (loss) from operations $(266,864) $126,027
 $—
 $(140,837) $(242,166) $86,086
 $—
 $(156,080)
        
Nine months ended September 30, 2018        
Sales and other revenues $546,300
 $1,248,886
 $(406,771) $1,388,415
Cost of products sold $482,842
 $964,343
 $(406,771) $1,040,414
Operating expenses $82,729
 $42,372
 $—
 $125,101
Selling, general and administrative expenses $22,146
 $77,279
 $—
 $99,425
Depreciation and amortization $17,986
 $12,037
 $—
 $30,023
Income (loss) from operations $(59,403) $152,855
 $—
 $93,452

(1) Rack back consists of our PCLI base oil production activities, by-product sales to third parties and intra-segment base oil sales to rack forward.
(2) Rack forward activities include the purchase of base oils from rack back and the blending, packaging, marketing and distribution and sales of finished lubricants and specialty products to third parties.
(3) Intra-segment sales of rack back produced base oils to rack forward are eliminated under the “Eliminations” column.
(4) During the three months ended June 30, 2019, a goodwill impairment charge of $152.7 million was recorded in the PCLI reporting unit within the Lubricants and Specialty Products segment. We have separately allocated this goodwill impairment charge for purposes of management’s discussion and analysis presentation of Rack Back and Rack Forward results entirely to Rack Back.


Results of Operations – Three Months Ended SeptemberJune 30, 20192020 Compared to Three Months Ended SeptemberJune 30, 20182019

Summary
Net incomeloss attributable to HollyFrontier stockholders for the three months ended SeptemberJune 30, 20192020 was $261.8$(176.7) million ($1.60(1.09) per basic and $1.58 per diluted share), a $80.7$373.6 million decrease compared to net income of $342.5$196.9 million ($1.951.16 per basic and $1.93$1.15 per diluted share) for the three months ended SeptemberJune 30, 2018.2019. Net income decreased due principally to long-lived asset impairment charges of $436.9 million, lower gross refining margins offset by higherand lower refining segment sales volumes. For the three months ended SeptemberJune 30, 2019,2020, lower of cost or market inventory reserve adjustments decreasedincreased pre-tax earnings by $34.1$269.9 million compared to a decrease to pre-tax earnings of $17.8$47.8 million for the three months ended SeptemberJune 30, 2018.2019. Refinery gross margins for the three months ended SeptemberJune 30, 20192020 decreased to $17.23$8.44 per barrel sold from $19.41$19.64 for the three months ended SeptemberJune 30, 2018. During the2019. The three months ended SeptemberJune 30, 2019 our Cheyenne Refinery and Woods Cross Refinery were each grantedincluded a one-year small refinery exemption from the EPA for the 2018 calendar year, at which time we recorded a total $36.6 million reduction to costgoodwill impairment charge of products sold.$152.7 million.

Sales and Other Revenues
Sales and other revenues decreased 7%57% from $4,770.8$4,782.6 million for the three months ended SeptemberJune 30, 20182019 to $4,424.8$2,062.9 million for the three months ended SeptemberJune 30, 20192020 due to a year-over-year decrease in thirdsecond quarter sales prices offset by higherand lower refined product sales volumes. Sales and other revenues for the three months ended SeptemberJune 30, 2020 and 2019 and 2018 included $29.9$19.2 million and $25.6$28.4 million, respectively, in HEP revenues attributable to pipeline and transportation services provided to unaffiliated parties. Additionally, sales and other revenues included $529.6$353.6 million and $474.3$545.3 million in unaffiliated revenues related to our Lubricants and Specialty Products segment for the three months ended SeptemberJune 30, 2020 and 2019, and 2018, respectively. Sonneborn contributed $88.1 million in sales and other revenues for the three months ended September 30, 2019.

Table of Content

Cost of Products Sold
Total cost of products sold decreased 9%65% from $3,770.1$3,752.7 million for the three months ended SeptemberJune 30, 20182019 to $3,437.8$1,307.1 million for the three months ended SeptemberJune 30, 2019,2020 due principally to lower crude oil costs partially offset by higherand lower refined product sales volumes. Additionally, during the thirdsecond quarter of 2019,2020, we recognized a lower of cost or market inventory valuation chargeadjustment benefit of $34.1$269.9 million compared to $17.8a charge of $47.8 million for the same period of 2018,2019, resulting in a new $209.7$530.9 million inventory lower of cost or market reserve at SeptemberJune 30, 2019.2020. The lower of cost or market reserve at SeptemberJune 30, 20192020 is based on market conditions and prices at that time. Current period cost of products sold includes $48.4 million in costs attributable to our Sonneborn operations. During the third quarter of 2019, we recorded a $36.6 million RINs cost reduction as a result of our Cheyenne Refinery and Woods Cross Refinery small refinery exemptions.

Gross Refinery Margins
Gross refinery margin per barrel sold decreased 11%57% from $19.41$19.64 for the three months ended SeptemberJune 30, 20182019 to $17.23$8.44 for the three months ended SeptemberJune 30, 2019.2020. This was due to the effects of a decrease in the average per barrel sold sales price during the current year quarter, partially offset by decreased crude oil and feedstock prices. Gross refinery margin per barrel does not include the non-cash effects of lower of cost or market inventory valuation adjustments or depreciation and amortization. See “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q for a reconciliation to the income statement of sale prices of products sold and cost of products purchased.

Operating Expenses
Operating expenses, exclusive of depreciation and amortization, increaseddecreased 9% from $317.2$333.3 million for the three months ended SeptemberJune 30, 20182019 to $345.6$303.4 million for the three months ended SeptemberJune 30, 20192020 due principally to lower repair and maintenance costs for the three months ended June 30, 2020 compared to prior period. Prior year period operating expenses included higher repair and maintenance costs. Current period operating expenses include $15.2 millioncosts related to a February 2019 fire in costs attributable toan FCC unit at our Sonneborn operations.El Dorado Refinery.

Selling, General and Administrative Expenses
Selling, general and administrative expenses increased 23%decreased 12% from $71.1 million for the three months ended September 30, 2018 to $87.6 million for the three months ended September 30, 2019 due principally to higher legal and professional fees and salary costs. Current period selling, general and administrative expenses include $7.9 million in costs attributable to our Sonneborn operations. Additionally, direct integration and regulatory costs of our recently acquired Sonneborn operations were $3.9$85.3 million for the three months ended SeptemberJune 30, 2019.2019 to $75.4 million for the three months ended June 30, 2020 due principally to lower incentive compensation costs and employee-related travels expenses. We incurred $0.6 million and $3.6 million in direct acquisition and integration costs of our Sonneborn business during the three months ended June 30, 2020 and 2019, respectively.

Depreciation and Amortization Expenses
Depreciation and amortization increased 17%3% from $108.9$126.9 million for the three months ended SeptemberJune 30, 20182019 to $127.0$130.2 million for the three months ended SeptemberJune 30, 2019.2020. This increase was due principally to depreciation and amortization attributable to capitalized improvement projects and capitalized refinery turnaround costs. Current periodcosts, partially offset by lower depreciation expense resulting from the impaired assets in the current quarter.

Long-lived Asset and amortization expenses include $9.1Goodwill Impairments
During the three months ended June 30, 2020, we recorded long-lived asset impairment charges of $232.2 million in costs attributablethat related to our Sonneborn operations.Cheyenne Refinery and $204.7 million related to PCLI. During the three months ended June 30, 2019, we recorded a goodwill impairment charge of $152.7 million that related to PCLI. See Note 1 “Description of Business and Presentation of Financial Statements” in the Notes to Consolidated Financial Statements for additional information on these impairments.

Interest Income
Interest income for the three months ended SeptemberJune 30, 20192020 was $6.2$1.5 million compared to $5.1$4.6 million for the three months ended SeptemberJune 30, 2018.2019. This increasedecrease was primarily due to higher averagelower interest rates on cash balances on handinvestments during the current year quarter.

Interest Expense
Interest expense was $36.032.7 million for the three months ended SeptemberJune 30, 20192020 compared to $32.434.3 million for the three months ended SeptemberJune 30, 20182019. This increasedecrease was primarily due to lower market interest attributable to higher HEP debt levelsrates on HEP’s credit facility and HEP’s refinancing of its 6.0% senior notes due 2024, partially offset by an unrealized loss on the mark-to-market change of the fair value of the embedded derivative in our catalyst financing arrangements during the current year quarter relative to the same period of 2018.quarter. For the three months ended SeptemberJune 30, 20192020 and 2018,2019, interest expense included $18.8$12.1 million and $18.0$19.2 million, respectively, in interest costs attributable to HEP operations.

Gain on Sales-type Leases
During the second quarter of 2020, HEP and Delek US Holdings, Inc. renewed the original throughput agreement on specific HEP assets. Portions of the new throughput agreement meet the definition of sales-type leases, which resulted in an accounting gain of $33.8 million upon the initial recognition of the sales-type lease during the three months ended June 30, 2020.

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Gain on Foreign Currency Transactions
Remeasurement adjustments resulting from the foreign currency conversion of the intercompany financing structurenotes payable by PCLI net of mark-to-market valuations on our PCLI acquisition from local currencies toforeign exchange forward contracts with banks which hedge the U.S. dollar resulted inforeign currency exposure on these intercompany notes were net gains of $0.4$2.3 million and $0.3$2.2 million for the three months ended SeptemberJune 30, 20192020 and 2018,2019, respectively. For the three months ended SeptemberJune 30, 20192020 and 2018,2019, gain on foreign currency translationtransactions included a gainloss of $5.7$14.3 million and a loss of $7.1 million, respectively, on foreign exchange forward contracts (utilized as an economic hedge).

Income Taxes
For the three months ended SeptemberJune 30, 2019,2020, we recorded an income tax benefit of $30.9 million compared to income tax expense of $103.0 million compared to $116.3$89.3 million for the three months ended SeptemberJune 30, 2018.2019. This decrease was due principally to a pre-tax loss during the three months ended June 30, 2020 compared to pre-tax earnings in the same period of 2019. Our effective tax rates before consideration ofwere 17.0% and 29.2% for the three months ended June 30, 2020 and 2019, respectively. The year-over-year decrease in the effective tax rate is due principally to the relationship between the pre-tax results and the earnings attributable to the noncontrolling interest were 25.7% and 24.3%that is not included in income for the three months ended September 30, 2019 and 2018, respectively.tax purposes.


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Results of Operations – NineSix Months Ended SeptemberJune 30, 20192020 Compared to NineSix Months Ended SeptemberJune 30, 20182019

Summary
Net incomeloss attributable to HollyFrontier stockholders for the ninesix months ended SeptemberJune 30, 20192020 was $711.8(481.3) million ($4.23(2.97) per basic and $4.20 per diluted share), a $244.3931.3 million decrease compared to net income attributable to HollyFrontier stockholders of $956.1$450.0 million ($5.422.64 per basic and $5.37$2.62 per diluted share) for the ninesix months ended SeptemberJune 30, 2018.2019. Net income decreased due principally to a goodwilllong-lived asset impairment chargecharges of $152.7$436.9 million, offset by an increase inlower gross refining margins and lower refining segment sales volumes. For the ninesix months ended SeptemberJune 30, 2019,2020, lower of cost or market inventory reserve adjustments increaseddecreased pre-tax earnings by $150.5$290.6 million compared to $192.9an increase to pre-tax earnings of $184.5 million for the ninesix months ended SeptemberJune 30, 2018.2019. Refinery gross margins for the ninesix months ended SeptemberJune 30, 2020 decreased to $10.00 per barrel sold from $16.39 for the six months ended June 30, 2019. The six months ended June 30, 2019 increased to $16.69 per produced barrel from $16.25 for the nine months ended September 30, 2018. During the nine months ended September 30, 2019, our Cheyenne Refinery and Woods Cross Refinery were each grantedincluded a one-year small refinery exemption from the EPA for the 2018 calendar year, at which time we recorded a total $36.6 million reduction to costgoodwill impairment charge of products sold. During the nine months ended September 30, 2018, our Cheyenne Refinery was granted a one-year small refinery exemption from the EPA for the 2015 and 2017 calendar years and our Woods Cross Refinery was granted a one-year small refinery exemption for 2017. As a result of these exemptions, we recorded reductions totaling $97.0 million to our cost of products sold in 2018.$152.7 million.

Sales and Other Revenues
Sales and other revenues decreased 2%37% from $13,370.5$8,679.9 million for the ninesix months ended SeptemberJune 30, 20182019 to $13,104.7$5,463.5 million for the ninesix months ended SeptemberJune 30, 20192020 due to a year-over-year decrease in sales prices partially offset by higherand lower refined product sales volumes. Sales and other revenues for the ninesix months ended SeptemberJune 30, 2020 and 2019 and 2018 include $89.4$45.7 million and $77.8$59.5 million, respectively, in HEP revenues attributable to pipeline and transportation services provided to unaffiliated parties. Additionally, sales and other revenues included $1,568.2$877.1 million and $1,376.5$1,038.7 million in unaffiliated revenues related to our Lubricants and Specialty Products segment for the ninesix months ended SeptemberJune 30, 2020 and 2019, and 2018, respectively. Sonneborn contributed $253.5 million in sales and other revenues for the nine months ended September 30, 2019.

Cost of Products Sold
Total cost of products sold decreased 32% from $10,502.3$6,719.5 million for the ninesix months ended SeptemberJune 30, 20182019 to $10,157.4$4,561.3 million for the ninesix months ended SeptemberJune 30, 2019,2020 due principally to lower crude oil costs.costs and lower refined product sales volumes. Additionally, during the nine months ended September 30, 2019, we recognized a $150.5 million lower of cost or market inventory valuation benefitcharge of $290.6 million for the six months ended June 30, 2020 compared to $192.9a benefit of $184.5 million for the same period of last year,2019, resulting in a new $209.7$530.9 million inventorylower of cost or market reserve at SeptemberJune 30, 2019.2020. The lower of cost or market reserve at SeptemberJune 30, 20192020 is based on market conditions and prices at that time. Cost of products sold includes $163.7 million in costs attributable to our Sonneborn operations for the nine months ended September 30, 2019. During the nine months ended September 30, 2019, we recorded a $36.6 million RINs cost reduction as a result of our Cheyenne Refinery and Woods Cross Refinery small refinery exemptions. During the nine months ended September 30, 2018, we recorded a $97.0 million RINs cost reduction as a result of our Cheyenne Refinery and Woods Cross Refinery small refinery exemptions.

Gross Refinery Margins
Gross refinery margin per barrel sold increased 3%decreased 39% from $16.25$16.39 for the ninesix months ended SeptemberJune 30, 20182019 to $16.69$10.00 for the ninesix months ended SeptemberJune 30, 2019.2020. This was primarily due to the effects of a decrease in the average per barrel sold sales price during the current year-to-date period, partially offset by decreased crude oil and feedstock prices during the current year-to-date period.prices. Gross refinery margin per barrel does not include the non-cash effects of lower of cost or market inventory valuation adjustments or depreciation and amortization. See “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q for a reconciliation to the income statement of sales prices of products sold and cost of products purchased.

Operating Expenses
Operating expenses, exclusive of depreciation and amortization, increased 8%decreased 5% from $933.7664.8 million for the ninesix months ended SeptemberJune 30, 20182019 to $1,010.4631.7 million for the ninesix months ended SeptemberJune 30, 20192020 due principally to lower repair and maintenance costs compared to prior period. Prior year period operating expenses included higher repair and maintenance costs related to a February 2019 fire in an FCC unit at our El Dorado Refinery. Prior year period operating expenses included higher repair and maintenance costs as a result of the Woods Cross Refinery fire and resulting damage in March 2018. Current year operating expenses include $38.6 million in costs attributable to our Sonneborn operations.

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Selling, General and Administrative Expenses
Selling, general and administrative expenses increased 28%decreased 6% from $204.5173.4 million for the ninesix months ended SeptemberJune 30, 20182019 to $261.0163.1 million for the ninesix months ended SeptemberJune 30, 20192020 due principally to higher legallower incentive compensation costs and professional feesemployee travel-related expenses. We incurred $1.9 million and salary costs. Current year selling, general and administrative expenses include $21.0$16.2 million in costs attributable to our Sonneborn operations. Additionally, direct integrationacquisition and regulatory costs of our recently acquired Sonneborn operations were $20.1 million for the nine months ended September 30, 2019. We incurred $3.6 million in integration costs of our PCLISonneborn business during the ninesix months ended SeptemberJune 30, 2018.2020 and 2019, respectively.

Depreciation and Amortization Expenses
Depreciation and amortization increased 16%9% from $323.6$248.3 million for the ninesix months ended SeptemberJune 30, 20182019 to $375.3$270.8 million for the ninesix months ended SeptemberJune 30, 2019.2020. This increase was due principally to depreciation and amortization attributable to capitalized improvement projects and capitalized refinery turnaround costs. Current yearcosts, partially offset by lower depreciation and amortization expenses include $24.4 millionexpense resulting from the impaired assets in costs attributable to our Sonneborn operations.the current period.

Long-lived Asset and Goodwill ImpairmentImpairments
During the ninesix months ended SeptemberJune 30, 2020, we recorded long-lived asset impairment charges of $232.2 million that related to our Cheyenne Refinery and $204.7 million related to PCLI. During the six months ended June 30, 2019, we recorded a goodwill impairment chargescharge of $152.7 million that relaterelated to PCLI. See Note 1 “Description of Business and Presentation of Financial Statements” in the Notes to Consolidated Financial Statements for additional information on the PCLI impairment.these impairments.

Interest Income
Interest income for the ninesix months ended SeptemberJune 30, 20192020 was $17.1$5.6 million compared to $10.7$11.0 million for the ninesix months ended SeptemberJune 30, 2018.2019. This increasedecrease was primarily due to higherlower average cash balances during the current year-to-date period.and lower interest rates on cash investments.

Interest Expense
Interest expense was $106.9$55.3 million for the ninesix months ended SeptemberJune 30, 20192020 compared to $97.4$70.9 million for the ninesix months ended SeptemberJune 30, 2018.2019. This increasedecrease was primarily due to lower market interest attributablerates on HEP’s credit facility and HEP’s refinancing of its 6.0% senior notes due 2024. Additionally, we recorded an unrealized gain on the mark-to-market change in the fair value of the embedded derivative in our catalyst financing arrangements of $4.7 million for the six months ended June 30, 2020 compared to higher HEP debt levels during the current year relative toan unrealized loss of $1.3 million for the same period of 2018.in 2019. For the ninesix months ended SeptemberJune 30, 20192020 and 2018,2019, interest expense included $57.1$28.2 million and $53.2$38.3 million, respectively, in interest costs attributable to HEP operations.

Gain on Sales-type Leases
During the second quarter of 2020, HEP and Delek US Holdings, Inc. renewed the original throughput agreement on specific HEP assets. Portions of the new throughput agreement meet the definition of sales-type leases, which resulted in an accounting gain of $33.8 million upon the initial recognition of the sales-type lease during the six months ended June 30, 2020.

Loss on Early Extinguishment of Debt
For the six months ended June 30, 2020, HEP recorded a $25.9 million loss on the redemption of its $500 million aggregate principal amount of 6% senior notes maturing August 2024 at a redemption cost of $522.5 million.

Gain (Loss) on Foreign Currency Transactions
Remeasurement adjustments resulting from the foreign currency conversion of the intercompany financing structurenotes payable by PCLI net of mark-to-market valuations on our PCLI acquisition from local currencies toforeign exchange forward contracts with banks which hedge the U.S. dollar resulted inforeign currency exposure on these intercompany notes were a $4.9loss of $1.9 million gain for the ninesix months ended SeptemberJune 30, 2019, and2020 compared to a $5.5net gain of $4.5 million gain for the ninesix months ended SeptemberJune 30, 2018.2019. For the ninesix months ended SeptemberJune 30, 2020 and 2019, and 2018, gain / loss on foreign currency translationtransactions included a gain of $19.2 million and a loss of $9.0 million and a gain of $18.5$14.7 million, respectively, on foreign exchange forward contracts (utilized as an economic hedge).

Income Taxes
For the ninesix months ended SeptemberJune 30, 2019,2020, we recorded an income tax benefit of $193.1 million compared to income tax expense of $279.9 million compared to $318.7$176.8 million for the ninesix months ended SeptemberJune 30, 2018.2019. This decrease was due principally to a pre-tax loss during the six months ended June 30, 2020 compared to pre-tax earnings in the same period of 2019. Our effective tax rates before consideration ofwere 30.3% and 26.4% for the six months ended June 30, 2020 and 2019, respectively. The year-over-year increase in the effective tax rate is due principally to the relationship between the pre-tax results and the earnings attributable to the noncontrolling interest were 26.1% and 23.9% for the nine months ended September 30, 2019 and 2018, respectively. Our current year effective tax rate reflects the effects of the $152.7 million goodwill impairment charge that is not deductibleincluded in income for income tax purposes.


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LIQUIDITY AND CAPITAL RESOURCES

HollyFrontier Credit Agreement
We have a $1.35 billion senior unsecured revolving credit facility maturing in February 2022 (the “HollyFrontier Credit Agreement”). The HollyFrontier Credit Agreement may be used for revolving credit loans and letters of credit from time to time and is available to fund general corporate purposes. At SeptemberJune 30, 20192020, we were in compliance with all covenants, had no outstanding borrowings and had outstanding letters of credit totaling $4.9 million under the HollyFrontier Credit Agreement.

HollyFrontier Financing Arrangements
In December 2018, certain of our wholly-owned subsidiaries entered into financing arrangements whereby such subsidiaries sold a portion of their precious metals catalyst to a financial institution and then leased back the precious metals catalyst in exchange for total cash received of $32.5 million. The volume of the precious metals catalyst and the lease rate are fixed over the one-year term of each lease, and the lease payments are recorded as interest expense. AtThe leases mature on February 1, 2021. Upon maturity, we must repurchaseeither satisfy the precious metals catalystobligation at its then fair market value.

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value or refinance to extend the maturity.

HEP Credit Agreement
HEP has a $1.4 billion senior secured revolving credit facility maturing in July 2022 (the “HEP Credit Agreement”) and is available to fund capital expenditures, investments, acquisitions, distribution payments, working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit and has a $300 million accordion. During the ninesix months ended SeptemberJune 30, 2019,2020, HEP received advances totaling $269.5$168.0 million and repaid $257.0$138.5 million under the HEP Credit Agreement. At SeptemberJune 30, 2019,2020, HEP was in compliance with all of its covenants, had outstanding borrowings of $935.5$995.0 million and no outstanding letters of credit under the HEP Credit Agreement.

HEP Senior Notes
On February 4, 2020, HEP closed a private placement of $500 million in aggregate principal amount of 5.0% HEP senior unsecured notes maturing February 2028. On February 5, 2020, HEP redeemed its existing $500 million aggregate principal amount of 6.0% senior notes maturing August 2024 at a redemption cost of $522.5 million. HEP recognized a $25.9 million early extinguishment loss consisting of a $22.5 million debt redemption premium and unamortized discount and financing costs of $3.4 million. HEP funded the $522.5 million redemption with proceeds from the issuance of its 5.0% senior notes and borrowings under the HEP Credit Agreement.

See Note 119 “Debt” in the Notes to Consolidated Financial Statements for additional information on our debt instruments.

HEP Common Unit Continuous Offering Program
In May 2016, HEP established a continuous offering program under which HEP may issue and sell common units from time to time, representing limited partner interests, up to an aggregate gross sales amount of $200 million. During the ninesix months ended SeptemberJune 30, 2019,2020, HEP did not issue any common units under this program. As of SeptemberJune 30, 2019,2020, HEP has issued 2,413,153 units under this program, providing $82.3 million in gross proceeds.

HEP intends to use the net proceeds for general partnership purposes, which may include funding working capital, repayment of debt, acquisitions and capital expenditures. Amounts repaid under HEP’s credit facility may be reborrowed from time to time.

Liquidity
We believe our current cash and cash equivalents, along with future internally generated cash flow and funds available under our credit facilities, will provide sufficient resources to fund currently planned capital projects and our liquidity needs for the foreseeable future. We expect that, to the extent necessary, we can raise additional funds from time to time through equity or debt financings in the public and private capital markets. In addition, subject to our current cash conservation strategies as discussed above in “Outlook,” components of our growth strategy include the expansion of existing units at our facilities and selective acquisition of complementary assets for our refining operations intended to increase earnings and cash flow. We also expect to use cash for payment of cash dividends, which are at the discretion of our Board of Directors, and, once commodity prices and demand for products normalize, for the repurchases of our common stock under our share repurchase program, support of our master limited partnership and the payment of cash dividends.program.

AsOur standalone (excluding HEP) liquidity was over $2.2 billion at June 30, 2020, consisting ofSeptember 30, 2019, our cash and cash equivalents totaled $981.9totaling $883.6 million. and an undrawn $1.35 billion credit facility maturing in 2022. Our earliest standalone (excluding HEP) debt maturity is $1.0 billion of senior notes in 2026.

We consider all highly-liquid instruments with a maturity of three months or less at the time of purchase to be cash equivalents. Cash equivalents are stated at cost, which approximates market value. These primarily consist of investments in conservative, highly-rated instruments issued by financial institutions, government and corporate entities with strong credit standings and money market funds.

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In September 2018,November 2019, our Board of Directors approved a $1$1.0 billion share repurchase program, which replaced all existing share repurchase programs, authorizing us to repurchase common stock in the open market or through privately negotiated transactions. The timing and amount of stock repurchases will depend on market conditions and corporate, regulatory and other relevant considerations. This program may be discontinued at any time by the Board of Directors. As of SeptemberJune 30, 2019,2020, we had remaining authorization to repurchase up to $313.2 millionnot repurchased common stock under this stock repurchase program. In addition, we are authorized by our Board of Directors to repurchase shares in an amount sufficient to offset shares issued under our compensation programs. In order to preserve liquidity, we do not intend to repurchase common stock under our $1.0 billion share repurchase program until commodity prices and demand for products normalize.

Cash and cash equivalents decreased $172.9increased $17.3 million for the ninesix months ended SeptemberJune 30, 2019.2020. Net cash used for investing and financing activities of $856.8 million, and $729.3 million, respectively, exceeded net cash provided by operating activities of $1,411.4 million.$309.3 million exceeded net cash used by investing and financing activities of $131.7 million, and $155.5 million, respectively.
 
Cash Flows – Operating Activities

NineSix Months Ended SeptemberJune 30, 20192020 Compared to NineSix Months Ended SeptemberJune 30, 20182019
Net cash flows provided by operating activities were $1,411.4$309.3 million for the ninesix months ended SeptemberJune 30, 20192020 compared to $1,129.9$969.6 million for the ninesix months ended SeptemberJune 30, 2018, an increase of $281.5 million. Net income for the nine months ended September 30, 2019, was $791.3 million, a decrease of $222.6$660.2 million. Net loss for the six months ended June 30, 2020 of $(443.7) million, was a decrease of $937.0 million compared to $1,013.9net income of $493.3 million for the ninesix months ended SeptemberJune 30, 2018.2019. Non-cash adjustments to net income consisting of depreciation and amortization, long-lived asset and goodwill impairment,impairments, lower of cost or market inventory valuation adjustment, earnings of equity method investments, inclusive of distributions, loss on early extinguishment of debt, gain on sales-type leases, gain / loss on sale of assets, deferred income taxes, equity-based compensation expense and fair value changes to derivative instruments totaled $531.5$877.5 million for the ninesix months ended SeptemberJune 30, 20192020 compared to $256.4$327.8 million for the same period in 2018.2019. Adjusted for non-cash items, changes in working capital decreased operating cash flows by $103.3 million and increased operating cash flows by $244.3 million and decreased operating cash flows by $33.5$246.9 million, for the ninesix months ended SeptemberJune 30, 20192020 and 2018,2019, respectively. Additionally, for the ninesix months ended SeptemberJune 30, 2019,2020, turnaround expenditures increaseddecreased to $152.4$49.2 million from $114.6110.3 million from the same period of 20182019.

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Cash Flows – Investing Activities and Planned Capital Expenditures

NineSix Months Ended SeptemberJune 30, 20192020 Compared to NineSix Months Ended SeptemberJune 30, 20182019
Net cash flows used for investing activities were $856.8131.7 million for the ninesix months ended SeptemberJune 30, 20192020 compared to $259.2782.3 million for the ninesix months ended SeptemberJune 30, 2018, an increase2019, a decrease of $597.6$650.6 million. CurrentCash expenditures for properties, plants and equipment for the first six months of 2020 increased to $129.7 million from $120.5 million for the same period in 2019. These include HEP capital expenditures of $30.7 million and $17.8 million for the six months ended June 30, 2020 and 2019, respectively. Additionally, HEP invested $2.4 million in the Cushing Connect Pipeline & Terminal LLC joint venture. Prior year investing activities reflectreflected a net cash outflow of $662.7 million upon the acquisition of Sonneborn, and prior year investing activities reflect a net cash outflow of $54.1 million upon the acquisition of Red Giant Oil. Cash expenditures for properties, plants and equipment for the first nine months of 2019 decreased to $195.1 million from $209.1 million for the same period in 2018. These include HEP capital expenditures of $23.8 million and $41.1 million for the nine months ended September 30, 2019 and 2018, respectively.Sonneborn.

Planned Capital Expenditures

HollyFrontier Corporation
Each year our Board of Directors approves our annual capital budget, which includes specific projects that management is authorized to undertake. Additionally, when conditions warrant or as new opportunities arise, additional projects may be approved. The funds appropriated for a particular capital project may be expended over a period of several years, depending on the time required to complete the project. Therefore, our planned capital expenditures for a given year consist of expenditures appropriated in that year’s capital budget plus expenditures for projects appropriated in prior years which have not yet been completed. During 2019, we expect to spend approximately $600.0 million to $640.0 million in cash for capital projects and refinery turnarounds appropriated in 2019 and prior years. Refinery turnaround spending is amortized over the useful life of the turnaround. Our expected capital and turnaround cash spending for 2019 is as follows:

 Expected Cash Spending Range
 (In millions)
Type:   
Capital$300.0
-$320.0
Turnarounds300.0
-320.0
Total$600.0
-$640.0

The refining industry is capital intensive and requires on-going investments to sustain our refining operations. This includes replacement of, or rebuilding, refinery units and components that extend the useful life. We also invest in projects that improve operational reliability and profitability via enhancements that improve refinery processing capabilities as well as production yield and flexibility. Our capital expenditures also include projects related to environmental, health and safety compliance and include initiatives as a result of federal and state mandates.

Our refinery operations and related emissions are highly regulated at both federal and state levels, and we invest in our facilities as needed to remain in compliance with these standards. Additionally, when faced with new emissions or fuels standards, we seek to execute projects that facilitate compliance and also improve the operating costs and / or yields of associated refining processes.

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HEP
Each year the Holly Logistic Services, L.L.C. board of directors approves HEP’s annual capital budget, which specifies capital projects that HEP management is authorized to undertake. Additionally, at times when conditions warrant or as new opportunities arise, special projects may be approved. The funds allocated for a particular capital project may be expended over a period in excess of a year, depending on the time required to complete the project. Therefore, HEP’s planned capital expenditures for a given year consist of expenditures approved for capital projects included in its current year capital budget as well as, in certain cases, expenditures approved for capital projects in capital budgets for prior years. The 2019 HEP capital budget is comprised of $7.0 million to $8.0 million for maintenance capital expenditures and $35.0 million expansion capital expenditures. HEP expects the majority of the expansion capital budget in 2020 to be invested in refined product pipeline expansions, crude system enhancements, new storage tanks and enhanced blending capabilities at its racks.the Cushing Connect joint venture. In addition, HEP may spend funds periodically to perform capital upgrades or additions to its assets where a customer reimburses HEP for such costs. The upgrades or additions would generally benefit the customer over the remaining livelife of the related service agreements.

Due to the COVID-19 pandemic and resulting decline in U.S. and global economic activities, we have reduced our 2020 expected total consolidated capital expenditures by approximately 15% from our approved annual capital budget. Expected capital and turnaround cash spending for 2020 is as follows:
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 Expected Cash Spending Range
 (In millions)
HollyFrontier Capital Expenditures   
Refining$202.0
 $221.0
Renewable Diesel Unit150.0
 180.0
Lubricants and Specialty Products30.0
 45.0
Turnarounds and catalyst85.0
 110.0
Total HollyFrontier467.0
 556.0
    
HEP   
Maintenance8.0
 12.0
Expansion and joint venture investment45.0
 50.0
Refining unit turnarounds5.0
 7.0
Total HEP58.0
 69.0
Total$525.0
 $625.0

Cash Flows – Financing Activities

NineSix Months Ended SeptemberJune 30, 20192020 Compared to NineSix Months Ended SeptemberJune 30, 20182019
Net cash flows used for financing activities were $729.3$155.5 million for the ninesix months ended SeptemberJune 30, 20192020 compared to $423.4$429.9 million for the ninesix months ended SeptemberJune 30, 2018, an increase2019, a decrease of $305.9$274.3 million. During the ninesix months ended SeptemberJune 30, 2019,2020, we purchased $472.0$1.2 million of treasury stock and paid $168.0$114.4 million in dividends. Also during this period, HEP received $269.5$168.0 million and repaid $257.0$138.5 million under the HEP Credit Agreement, paid $522.5 million upon the redemption of HEP’s 6.0% senior notes and received $491.3 million in net proceeds from issuance of HEP 5.0% senior notes, paid distributions of $51.0 million to noncontrolling interests and received contributions from noncontrolling interests of $13.3 million. During the six months ended June 30, 2019, we purchased $267.0 million of treasury stock and paid $113.5 million in dividends. Also during this period, HEP received $175.0 million and repaid $156.5 million under the HEP Credit Agreement and paid distributions of $100.1 million to noncontrolling interests. During the nine months ended September 30, 2018, we purchased $177.7 million of treasury stock and paid $175.9 million in dividends. Also during this period, HEP received $256.0 million and repaid $347.0 million under the HEP Credit Agreement, received $114.9 million in proceeds from the issuance of its common units and paid distributions of $93.1$66.7 million to noncontrolling interests.

Contractual Obligations and Commitments

HollyFrontier Corporation

There were no significant changes to our long-term contractual obligations during the ninesix months ended SeptemberJune 30, 2019.2020.

HEP

In February 2020, HEP issued $500 million in aggregate principal amount of 5.0% HEP senior notes maturing February 2028 and redeemed its existing $500 million 6.0% senior notes maturing August 2024.

During the ninesix months ended SeptemberJune 30, 2019,2020, HEP had net borrowings of $12.5$29.5 million resulting in $935.5$995.0 million of outstanding borrowings under the HEP Credit Agreement at SeptemberJune 30, 2019. 2020.

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There were no other significant changes to HEP’s long-term contractual obligations during this period.


CRITICAL ACCOUNTING POLICIES

Our discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these 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 as of the date of the financial statements. Actual results may differ from these estimates under different assumptions or conditions.

Our significant accounting policies are described in “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Critical Accounting Policies” in our Annual Report on Form 10-K for the year ended December 31, 20182019. Certain critical accounting policies that materially affect the amounts recorded in our consolidated financial statements include the use of the last-in, first-out (“LIFO”) method of valuing certain inventories, assessing the possible impairment of certain long-lived assets and goodwill, and assessing contingent liabilities for probable losses.

Inventory Valuation: Inventories related to our refining operations are stated at the lower of cost, using the LIFO method for crude oil and unfinished and finished refined products, or market. In periods of rapidly declining prices, LIFO inventories may have to be written down to market value due to the higher costs assigned to LIFO layers in prior periods. In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. An actual valuation of inventory under the LIFO method is made at the end of each year based on the inventory levels at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and are subject to the final year-end LIFO inventory valuation.

At SeptemberJune 30, 2019,2020, our lower of cost or market inventory valuation reserve was $209.7$530.9 million. This amount, or a portion thereof, is subject to reversal as a reduction to cost of products sold in subsequent periods as inventories giving rise to the reserve are sold, and a new reserve is established.

Inventories consisting of process chemicals, materials and maintenance supplies and RINs are stated at the lower of weighted-average cost or net realizable value. Inventories of our Petro-Canada Lubricants and Sonneborn businesses are stated at the lower of cost, using the FIFO method, or net realizable value.

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Goodwill and Long-lived Assets: As of SeptemberJune 30, 2019,2020, our goodwill balance was $2.4 billion, with goodwill assigned to our Refining, Lubricants and Specialty Products and HEP segments of $1,733.5 million, $324.1$327.6 million and $312.9 million, respectively. Goodwill represents the excess of the cost of an acquired entity over the fair value of the assets acquired and liabilities assumed. Goodwill is not subject to amortization and is tested annually or more frequently 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. Our goodwill impairment testing first entails either a quantitative assessment or an optional qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If we determine that based on the qualitative factors that it is more likely than not that the fair value of the reporting unit is greater than its carrying amount, a quantitative test is performed in which we estimate the fair value of the related reporting unit. If the carrying amount of a reporting unit exceeds its fair value, the goodwill of that reporting unit is impaired, and we measure goodwill impairment as the excess of the carrying amount of reporting unit over the related fair value.

OurFor purposes of long-lived asset impairment evaluation, we have grouped our long-lived assets principally consist ofas follows: (i) our refining assets that are organized as refiningrefinery asset groups, and thewhich include certain HEP logistics assets, of(ii) our Lubricants and Specialty Products business. Theasset groups and (iii) our HEP asset groups, which comprises HEP assets not included in our refinery asset groups. These asset groups also constitute our individual refinery reporting units that are usedrepresent the lowest level for testing and measuring goodwill impairments.which independent cash flows can be identified. Our long-lived assets are evaluated for impairment by identifying whether indicators of impairment exist and if so, assessing whether the long-lived assets are recoverable from estimated future undiscounted cash flows. The actual amount of impairment loss measured, if any, is equal to the amount by which the asset group’s carrying value exceeds its fair value.

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Goodwill impairmentand long-lived asset impairments
Due to the recent economic slowdown caused by the COVID-19 pandemic, we determined that indicators of potential goodwill impairment for our Refining and Lubricants and Specialty Products reporting units were present. In addition, we determined that these indicators were also evidence of potential long-lived asset impairments. These indicators included reductions in the prices of our finished goods and raw materials and the related decrease in our gross margins, as well as the recent decline in our common share price which has resulted in a decrease in our market capitalization. Additionally, our recent announcement of the conversion of our Cheyenne Refinery to renewable diesel production was also considered a triggering event requiring assessment of potential impairments to the carrying value of our Cheyenne Refinery asset group. During the second quarter of 2019,2020, we performed interim goodwill and long-lived asset impairment testing of the PCLI reporting unit included in our Lubricants and Specialty Products segment. We elected to perform this interim assessment due to the recent reorganization of our reporting unit structure within the Lubricants and Specialty Products segment, combined with the identification of events and circumstances which were indicators of potential goodwill impairment at PCLI, including recent declines in gross margins to lower than historic levels. These recent lower gross margins are in the base oil market which is largely attributed to the increase in global supply of base oils with a current outlook for continued near-term softness.

Our interim goodwill impairment testing was performed as of May 31, 2019. The estimated fair values2020.

In performing our impairment tests of goodwill and long-lived assets we developed cash flow forecasts for each of our goodwill reporting units within our Lubricants and Specialty Products segment were derived using a combination of both income and market approaches. The income approach reflects expected future cash flowsasset groups. Significant judgment is involved in performing these fair value estimates since the results are based on estimated future production volumes,forecasted financial information. The cash flow forecasts include significant assumptions such as planned utilization, end-user demand, selling prices, gross margins, operating costs and capital expenditures. Another key assumption applied to these forecasts to determine the fair value of a reporting unit or an asset group is the discount rate. The discount rate is intended to reflect the weighted average cost of capital for a market participant and the risks associated with the realization of the estimated future cash flows. Assumptions about the effects of the COVID-19 pandemic on future demand and market conditions are inherently subjective and difficult to forecast. Our market approach includes both the guideline public company and guideline transaction methods. Both methods utilize pricing multiples derived from historical market transactions of other like-kind assets.fair value estimates are based on projected cash flows, which we believe to be reasonable.

As a result of our long-lived asset impairment testing, we determined that the carrying value of the long-lived assets of our Cheyenne Refinery and PCLI reporting unit’sasset groups were not recoverable, and thus recorded long-lived asset impairment charges of $232.2 million and $204.7 million, respectively, in the second quarter of 2020. Our testing did not result in any other impairment of long-lived assets.

Our interim goodwill withinimpairment testing indicated that the fair values of our Refining and Lubricants and Specialty Products segmentreporting units were in excess of their respective carrying amounts ranging from 9% to 283%; therefore, there was fully impairedno impairment of goodwill at our Refining and aLubricants and Specialty Products reporting units. Increasing the discount rate by 1.0% or reducing the terminal cash flow growth rate by 1.0% would not have changed the results of our goodwill impairment charge of $152.7 million was recorded. Our testing did not identify any other impairments.testing.

We performedA reasonable expectation exists that further deterioration in our operating results or overall economic conditions could result in an impairment of goodwill and / or additional long-lived asset impairments at some point in the future. Future impairment charges could be material to our results of operations and financial condition. Our annual goodwill impairment testing as ofis performed on July 1, 2019 and determined there was no additional impairment of goodwill attributable to our reporting units.1.

Contingencies
We are subject to proceedings, lawsuits and other claims related to environmental, labor, product and other matters. We are required to assess the likelihood of any adverse judgments or outcomes to these matters as well as potential ranges of probable losses. A determination of the amount of reserves required, if any, for these contingencies is made after careful analysis of each individual issue. The required reserves may change in the future due to new developments in each matter or changes in approach such as a change in settlement strategy in dealing with these matters.


RISK MANAGEMENT

We use certain strategies to reduce some commodity price and operational risks. We do not attempt to eliminate all market risk exposures when we believe that the exposure relating to such risk would not be significant to our future earnings, financial position, capital resources or liquidity or that the cost of eliminating the exposure would outweigh the benefit.

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Commodity Price Risk Management
Our primary market risk is commodity price risk. We are exposed to market risks related to the volatility in crude oil and refined products, as well as volatility in the price of natural gas used in our refining operations. We periodically enter into derivative contracts in the form of commodity price swaps, forward purchase and sales and futures contracts to mitigate price exposure with respect to our inventory positions, natural gas purchases, sales prices of refined products and crude oil costs.

Foreign Currency Risk Management
We are exposed to market risk related to the volatility in foreign currency exchange rates. We periodically enter into derivative contracts in the form of foreign exchange forward and foreign exchange swap contracts to mitigate the exposure associated with fluctuations on intercompany notes with our foreign subsidiaries that are not denominated in the U.S. dollar.

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As of SeptemberJune 30, 2019,2020, we have the following notional contract volumes related to all outstanding derivative instruments used to mitigate commodity price and foreign currency risk:
   Notional Contract Volumes by Year of Maturity    Notional Contract Volumes by Year of Maturity  
Derivative Instrument Total Outstanding Notional 2019 2020 2021 Unit of Measure Total Outstanding Notional 2020 2021 Unit of Measure
                
Natural gas price swaps - long 4,050,000
 450,000
 1,800,000
 1,800,000
 MMBTU 2,700,000
 900,000
 1,800,000
 MMBTU
Crude oil price swaps (basis spread) - long 7,418,000
 1,196,000
 6,222,000
 —
 Barrels 3,128,000
 3,128,000
 —
 Barrels
WTI and gasoline crack spread swaps - short 200,000
 200,000
 —
 —
 Barrels
NYMEX futures (WTI) - short 1,825,000
 1,713,000
 112,000
 —
 Barrels 890,000
 890,000
 —
 Barrels
Forward gasoline and diesel contracts - long 538,500
 538,500
 —
 —
 Barrels 464,000
 464,000
 —
 Barrels
Forward crude oil contracts -short 423,739
 423,739
 —
 —
 Barrels
Forward crude oil contracts - long 140,849
 140,849
 —
 —
 Barrels
Physical contracts - long 350,000
 350,000
 —
 —
 Barrels
Physical contracts - short 350,000
 350,000
 —
 —
 Barrels
Forward diesel contracts - short 200,000
 200,000
 —
 Barrels
Foreign currency forward contracts 434,443,896
 114,213,501
 320,230,395
 —
 U.S. dollar 422,074,120
 214,491,576
 207,582,544
 U.S. dollar
Forward commodity contracts (platinum) (1)
 41,147
 41,147
 —
 —
 Troy ounces 40,867
 —
 40,867
 Troy ounces

(1) Represents an embedded derivative within our catalyst financing arrangements, which may be refinanced or require repayment under certain conditions. See Note 119 “Debt” in the Notes to Consolidated Financial Statements for additional information on these financing arrangements.

The following sensitivity analysis provides the hypothetical effects of market price fluctuations to the commodity positions hedged under our derivative contracts:
 Estimated Change in Fair Value at June 30, Estimated Change in Fair Value at June 30
Commodity-based Derivative Contracts 2019 2018 2020 2019
 (In thousands) (In thousands)
Hypothetical 10% change in underlying commodity prices $8,432
 $14,837
 $2,826
 $2,902

Interest Rate Risk Management
The market risk inherent in our fixed-rate debt is the potential change arising from increases or decreases in interest rates as discussed below.

For the fixed rate HollyFrontier Senior Notes and HEP Senior Notes, changes in interest rates will generally affect fair value of the debt, but not earnings or cash flows. The outstanding principal, estimated fair value and estimated change in fair value (assuming a hypothetical 10% change in the yield-to-maturity rates) for this debt as of SeptemberJune 30, 20192020 is presented below:
  
Outstanding
Principal
 
Estimated
Fair Value
 
Estimated
Change in
Fair Value
  (In thousands)
HollyFrontier Senior Notes $1,000,000
 $1,121,460
 $23,042
HEP Senior Notes $500,000
 $523,220
 $10,800

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Outstanding
Principal
 
Estimated
Fair Value
 
Estimated
Change in
Fair Value
  (In thousands)
HollyFrontier Senior Notes $1,000,000
 $1,105,120
 $20,828
HEP Senior Notes $500,000
 $477,835
 $17,322

For the variable rate HEP Credit Agreement, changes in interest rates would affect cash flows, but not the fair value. At SeptemberJune 30, 20192020, outstanding borrowings under the HEP Credit Agreement were $935.5995.0 million. A hypothetical 10% change in interest rates applicable to the HEP Credit Agreement would not materially affect cash flows.

Our operations are subject to hazards of petroleum processing operations, including fire, explosion and weather-related perils. We maintain various insurance coverages, including business interruption insurance, subject to certain deductibles. We are not fully insured against certain risks because such risks are not fully insurable, coverage is unavailable, or premium costs, in our judgment, do not justify such expenditures.

Financial information is reviewed on the counterparties in order to review and monitor their financial stability and assess their ongoing ability to honor their commitments under the derivative contracts. We have not experienced, nor do we expect to experience, any difficulty in the counterparties honoring their commitments.

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We have a risk management oversight committee consisting of members from our senior management. This committee oversees our risk enterprise program, monitors our risk environment and provides direction for activities to mitigate identified risks that may adversely affect the achievement of our goals.
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Item 3.Quantitative and Qualitative Disclosures About Market Risk

See “Risk Management” under “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”


Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles

Reconciliations of earnings before interest, taxes, depreciation and amortization (“EBITDA”) to amounts reported under generally accepted accounting principles in financial statements.

Earnings before interest, taxes, depreciation and amortization, which we refer to as EBITDA, is calculated as net income (loss) attributable to HollyFrontier stockholders plus (i) interest expense, net of interest income, (ii) income tax provision, and (iii) depreciation and amortization. EBITDA is not a calculation provided for under GAAP; however, the amounts included in the EBITDA calculation are derived from amounts included in our consolidated financial statements. EBITDA should not be considered as an alternative to net income or operating income as an indication of our operating performance or as an alternative to operating cash flow as a measure of liquidity. EBITDA is not necessarily comparable to similarly titled measures of other companies. EBITDA is presented here because it is a widely used financial indicator used by investors and analysts to measure performance. EBITDA is also used by our management for internal analysis and as a basis for financial covenants.

Set forth below is our calculation of EBITDA.
 Three Months Ended September 30, Nine Months Ended September 30, Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
 (In thousands) (In thousands)
Net income attributable to HollyFrontier stockholders $261,813
 $342,466
 $711,783
 $956,064
Add income tax expense 103,021
 116,258
 279,862
 318,742
Net income (loss) attributable to HollyFrontier stockholders $(176,677) $196,915
 $(481,300) $449,970
Add interest expense 36,027
 32,399
 106,938
 97,446
 32,695
 34,264
 55,334
 70,911
Subtract interest income (6,164) (5,136) (17,127) (10,660) (1,506) (4,588) (5,579) (10,963)
Add income tax expense (benefit) (30,911) 89,336
 (193,077) 176,841
Add depreciation and amortization 127,016
 108,885
 375,345
 323,605
 130,178
 126,908
 270,753
 248,329
EBITDA $521,713
 $594,872
 $1,456,801
 $1,685,197
 $(46,221) $442,835
 $(353,869) $935,088

Reconciliations of refinery operating information (non-GAAP performance measures) to amounts reported under generally accepted accounting principles in financial statements.

Refinery gross margin and net operating margin are non-GAAP performance measures that are used by our management and others to compare our refining performance to that of other companies in our industry. We believe these margin measures are helpful to investors in evaluating our refining performance on a relative and absolute basis. Refinery gross margin per produced barrel sold is total refining segment revenues less total refining segment cost of products sold, exclusive of lower of cost or market inventory valuation adjustments, divided by sales volumes of produced refined products sold. Net operating margin per barrel sold is the difference between refinery gross margin and refinery operating expenses per produced barrel sold. These two margins do not include the non-cash effects of long-lived asset impairment charges, lower of cost or market inventory valuation adjustments or depreciation and amortization. Each of these component performance measures can be reconciled directly to our consolidated statements of income. Other companies in our industry may not calculate these performance measures in the same manner.

Below are reconciliations to our consolidated statements of income for refinery net operating and gross margin and operating expenses, in each case averaged per produced barrel sold. Due to rounding of reported numbers, some amounts may not calculate exactly.

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Reconciliation of average refining segment net operating margin per produced barrel sold to refinery gross margin to total sales
and other revenues

 Three Months Ended September 30, Nine Months Ended September 30, Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
 (Dollars in thousands, except per barrel amounts) (Dollars in thousands, except per barrel amounts)
Consolidated                
Net operating margin per produced barrel sold $11.03
 $13.05
 $10.36
 $10.10
 $1.57
 $13.72
 $3.44
 $9.99
Add average refinery operating expenses per produced barrel sold 6.20
 6.36
 6.33
 6.15
 6.87
 5.92
 6.56
 6.40
Refinery gross margin per produced barrel sold 17.23
 19.41

16.69
 16.25
 8.44
 19.64

10.00
 16.39
Times produced barrels sold (BPD) 485,500
 447,770
 459,440
 455,640
 382,910
 469,100
 417,600
 446,190
Times number of days in period 92
 92
 273
 273
 91
 91
 182
 181
Refining segment gross margin 769,595
 799,592

2,093,379
 2,021,333
 294,090
 838,394

760,032
 1,323,663
Add (subtract) rounding 208
 (16) (278) (507) (23) 34
 150
 (365)
Total refining segment gross margin 769,803
 799,576

2,093,101
 2,020,826
 294,067
 838,428

760,182
 1,323,298
Add refining segment cost of products sold 3,177,167
 3,572,593
 9,598,539
 10,179,509
 1,433,437
 3,458,832
 3,902,188
 6,421,372
Refining segment sales and other revenues 3,946,970
 4,372,169
 11,691,640
 12,200,335
 1,727,504
 4,297,260
 4,662,370
 7,744,670
Add lubricants and specialty products segment sales and other revenues 537,718
 475,886
 1,576,398
 1,388,415
 357,287
 545,346
 883,890
 1,038,680
Add HEP segment sales and other revenues 135,895
 125,784
 401,143
 373,428
 114,807
 130,751
 242,661
 265,248
Subtract corporate, other and eliminations (195,755) (203,040) (564,491) (591,716) (136,668) (190,742) (325,446) (368,736)
Sales and other revenues $4,424,828
 $4,770,799
 $13,104,690
 $13,370,462
 $2,062,930
 $4,782,615
 $5,463,475
 $8,679,862


Reconciliation of average refining segment operating expenses per produced barrel sold to total operating expenses

 Three Months Ended September 30, Nine Months Ended September 30, Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018 2020 2019 2020 2019
 (Dollars in thousands, except per barrel amounts) (Dollars in thousands, except per barrel amounts)
Consolidated                
Average refinery operating expenses per produced barrel sold $6.20
 $6.36
 $6.33
 $6.15
 $6.87
 $5.92
 $6.56
 $6.40
Times produced barrels sold (BPD) 485,500
 447,770
 459,440
 455,640
 382,910
 469,100
 417,600
 446,190
Times number of days in period 92
 92
 273
 273
 91
 91
 182
 181
Refinery operating expenses 276,929
 261,999
 793,954
 764,997
 239,384
 252,714
 498,581
 516,866
Add (subtract) rounding (60) 11
 127
 (582) (25) 1
 (48) 346
Total refining segment operating expenses 276,869
 262,010
 794,081
 764,415
 239,359
 252,715
 498,533
 517,212
Add lubricants and specialty products segment operating expenses 57,974
 40,288
 170,655
 125,101
 47,840
 59,122
 101,971
 112,681
Add HEP segment operating expenses 44,924
 35,995
 123,045
 106,731
 34,737
 40,608
 69,718
 78,121
Subtract corporate, other and eliminations (34,189) (21,097) (77,359) (62,548) (18,577) (19,193) (38,518) (43,170)
Operating expenses (exclusive of depreciation and amortization) $345,578
 $317,196
 $1,010,422
 $933,699
 $303,359
 $333,252
 $631,704
 $664,844


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Item 4.Controls and Procedures

Evaluation of disclosure controls and procedures. Our principal executive officer and principal financial officer have evaluated, as required by Rule 13a-15(b) under the Securities Exchange Act of 1934 (the “Exchange Act”), our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e)) under the Exchange Act as of the end of the period covered by this Quarterly Report on Form 10-Q. Our disclosure controls and procedures are designed to provide reasonable assurance that the information we are required to disclose in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Based upon the evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective at the reasonable assurance level as of SeptemberJune 30, 20192020.

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

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PART II. OTHER INFORMATION
 
Item 1.Legal Proceedings

In the ordinary course of business, we may become party to legal, regulatory or administrative proceedings or governmental investigations, including environmental and other matters. Damages or penalties may be sought from us in some matters and certain matters may require years to resolve. While the outcome and impact of these proceedings and investigations on us cannot be predicted with certainty, based on advice of counsel and information currently available to us, management believes that the resolution of these proceedings and investigations through settlement or adverse judgment will not either individually or in the aggregate have a material adverse effect on our financial condition, results of operations or cash flows.

The environmental proceedings are reported to comply with SEC regulations which require us to disclose proceedings arising under provisions regulating the discharge of materials into the environment or protecting the environment if we reasonably believe that such proceedings may result in monetary sanctions of $100,000 or more.

Environmental Matters

Cheyenne
HollyFrontier Cheyenne Refining LLC (“HFCR”) has been in discussions with the Wyoming Department of Environmental Quality (“WDEQ”) and the United States Environmental Protection Agency (“EPA”) relating to Notices of Violations issued in late 2016 and 2018 for possiblealleged violations of air quality standardsemission limitations and requirements related to operation of certain refinery units at the Cheyenne Refinery.

Notices of Violations were issued by the WDEQ in late 2016 and 2018. On July 18, 2019, HFCR and WDEQ entered into a consent decree, pursuant to whichand on August 9, 2019, HFCR agreed to paypaid penalties in the amount of $117,000 related to alleged violations of air quality limits that occurred during the second quarter of 2016 through the second quarter of 2017. Separately, on October 23, 2019, HFCR received a Notice of Violation from the WDEQ for possible violations of air quality standards during the first and second quarters of 2019. No penalty demand has yet been made by the WDEQ relating to such possible violations. HFCR and WDEQ are in discussions to resolve WDEQ’s alleged violations of air quality limits that occurred during the third quarter of 2017 through calendar year 2018.2019.

On August 19, 2019 and October 30, 2019, HFCR received letters from the EPA providing a preliminary estimate of stipulated penalties related to the alleged violations that occurred during the third quarter of 2017 through the second quarter of 2019, pursuant to HFCR’s federal consent decree. HFCR responded to the EPA preliminary estimate of stipulated penalties related to the alleged violations that occurred during the third quarter of 2017 through calendar year 2018 in a letter dated September 18, 2019, and is in dialoguefollowed by meetings with the EPA and the WDEQ on November 14, 2019 and December 4, 2019, to discuss an appropriate resolution of all alleged violations.

Separately, on HFCR settled the allegations in the EPA's August 19, 2019 and October 23,30, 2019 letters, and pursuant to a demand letter dated January 9, 2020, HFCR received a Notice of Violation from the WDEQ for possible violations of air quality standards during the first and second quarters of 2019, which are not addressed by thewas assessed stipulated penalties totaling $700,000 pursuant to HFCR's federal consent decree. No penalty demand has yet been made byHFCR remitted payment of this amount to resolve the WDEQ relating to such possible violations.  HFCR and WDEQ are working towards settlement of these alleged violations.

It is too soon to predict the outcome of the negotiations and the ultimate penalty amount.

El Dorado
HollyFrontier El Dorado Refining LLC (“HFEDR”) ishas been engaged in discussions with, and has responded to document requests from, the EPA, and the U.S. Department of Justice (“DOJ”) and the State of Kansas regarding potentialalleged Clean Air Act civil violations relating to flaring devices and other equipment at the refinery. Topics of the discussions includeincluded (a) three information requests for activities beginning in January 2009, (b) Risk Management Program compliance issues relating to a November 2014 inspection and subsequent events, (c) a Notice of Violation issued by the EPA in August 2017 and (d) possible late reporting under the Emergency Planning and Community Right-to-Know Act for the release of sulfur dioxide and visible emissions from October 2018. HFEDR is currently in a dialogue with the EPA about a possible settlement of potential and alleged civil violations for the foregoing items. We are currently unable to estimate the final amount of civil penalties that might be included in any settlement. HFEDR will continue to work with the EPA and DOJ to resolve these civil matters. Some of the foregoing civil investigations resulted from fires that occurred at the El Dorado Refinery in September 2017, October 2018 and March 2019. An employee fatality occurred during the September 2017 event. On May 28, 2020, HFEDR reached a settlement in the form of a proposed consent decree with the EPA, the DOJ and the State of Kansas regarding the alleged Clean Air Act civil violations relating to flaring devices and other equipment at the refinery, as well as compliance with the Clean Air Act’s Risk Management Program (“RMP”).

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The proposed consent decree was lodged with the U.S. District Court for the District of Kansas, and the 30-day public comment period ended on July 18, 2020. On July 27, 2020, the EPA, the DOJ and the State of Kansas filed their Unopposed Motion to enter the Consent Decree with the U.S. District Court for the District of Kansas. The consent decree will become effective when entered by the district judge. Pursuant to the consent decree, among other terms and conditions, HFEDR is required to complete certain projects, implement protocols regarding the examination of its fired heaters and conduct a third party RMP audit of certain of its processes. In addition, HFEDR will be required to pay a civil penalty of $2 million to the United States and $2 million to the State of Kansas in two installments, the first half within 30 days of entry of the consent decree and the second within six months of entry of the consent decree. The proposed consent decree will resolve the alleged federal and state civil Clean Air Act liability for penalties and injunctive relief, other than potential civil penalties for RMP violations. Finally, as part of the settlement, a 2009 consent decree applicable to the refinery will be terminated.

The Occupational Safety and Health Administration (“OSHA”) completed an investigation ofconducted investigations into both the September 2017 and March 2019 eventevents identified above, and issued one citation to HFEDR on August 29, 2019. HFEDR is currently in dialogue with OSHA about possible settlement. HFEDR previously settled the OSHA claims related to an investigation of the September 2017 event.those investigations in 2018 and 2019, respectively. In April 2019, HFEDR became aware that the EPA also initiated a criminal investigation into one or more of the foregoing events. HFEDR has received a grand jury subpoena requesting certain documents be provided to the EPA with respect to the September 2017 event. We are cooperating with this investigation.

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Tulsa
HollyFrontier Tulsa Refining LLC (“HFTR”) operates under two Consent Decrees with the EPA and the Oklahoma Department of Environmental Quality (“ODEQ”) for the East and West refineries.Refineries. On December 13, 2017, during a meeting between the parties, ODEQ proposed stipulated penalties related to violations of the two Consent Decrees. The violations concern Clean Air Act regulated fuel gas and flare operations. On July 1, 2019, ODEQ issued a demand letter for stipulated penalties under the East Refinery Consent Decree as proposed in the 2017 meeting. In August 2019, HFTR paid the penalties set forth in the demand letter to ODEQ and the EPA satisfying the requirements of the East Refinery Consent Decree. On September 16, 2019, ODEQ issued a demand letter for stipulated penalties under the West Refinery Consent Decree. HFTR is workingFollowing discussions with ODEQ, in a letter dated April 17, 2020, ODEQ reduced its September 2019 demand for stipulated penalties. In May 2020, HFTR paid to resolve this matter. Additionally,ODEQ and the EPA the penalty set forth in the April 17, 2020 demand letter, which satisfied the requirements of the West Refinery Consent Decree. Separately, on April 3, 2019, during a meeting between the parties, the EPA notified HFTR of potential monitoring violations of the Consent Decrees. HFTR is working with the ODEQ and the EPA to document a settlement agreement for the additional actions.

Woods Cross
HollyFrontier Woods Cross Refining LLC (“HFWCR”) received an early settlement agreement from the Utah Department of Environmental Quality’s Division of Air Quality (“DAQ”) for alleged violations associated with operation of HFWCR’s diesel-fired emergency engines. HFWCR has reached an agreement in principle with the Utah Attorney General’s office to settle this matter. The agreement is subject to review and approval by the Utah Air Quality Board.

Federal Trade Commission

On July 23, 2019, the Federal Trade Commission (“FTC”) issued a Civil Investigative Demand and a related Subpoena DuceDuces Tecum requesting we provide specified information relating to the Sonneborn acquisition that closed on February 1, 2019. We are in the process of responding to the FTC request. Based on the limited information that we have at this time, we are unable to predict the outcome of this request. On December 14, 2018, we received early termination of the applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act from the FTC and Department of Justice with respect to the Sonneborn acquisition. On January 17, 2019, we received early termination of the applicable waiting period under the German antitrust laws with respect to the Sonneborn acquisition. Early termination is granted to transactions that the antitrust agencies determine raise no substantive competition concerns.

Renewable Fuel Standard

Various subsidiaries of HollyFrontier have intervenedmoved to intervene in threefour lawsuits brought by renewable fuel interest groups against the EPA in federal courts alleging violations of the Renewable Fuel Standard under the Clean Air Act and challenging the EPA’s handling of small refinery exemptions. We intervened to vigorously defend the EPA’s position on small refinery exemptions because we believe the EPA correctly applied applicable law to the matters at issue and will vigorously defendissue. The U.S. Court of Appeals for the EPA’s positionDC Circuit dismissed one of these four lawsuits on November 12, 2019 for lack of jurisdiction. On January 24, 2020, the U.S. Court of Appeals for the Tenth Circuit vacated the small refinery exemptions granted to two of our refineries for 2016 and remanded the case to the EPA for further proceedings. On March 24, 2020, various subsidiaries of HollyFrontier filed a Petition for Rehearing with the U.S. Court of Appeals for the Tenth Circuit. On April 7, 2020, the Tenth Circuit denied our request to reconsider its decision, and on April 15, 2020, the Tenth Circuit entered its mandate, remanding the matter back to the EPA. It is not clear at this time what steps the EPA will take with respect to our 2016 small refinery exemptions, or how the case will impact future small refinery exemptions.

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Other

We are a party to various other litigation and proceedings that we believe, based on advice of counsel, will not either individually or in the aggregate have a materially adverse impact on our financial condition, results of operations or cash flows.


Item 1A.Risk Factors

ThereExcept for the additional risk factor below, there have been no material changes in our risk factors as previously disclosed in Part 1, “Item 1A. Risk Factors” of our Annual Report on Form 10-K for the fiscal year ended December 31, 2018.2019 and in Part II, “Item 1A. Risk Factors” of our Quarterly Report on Form 10-Q for the quarter ended March 31, 2020. You should carefully consider the risk factors discussed below and in our 20182019 Form 10-K, which could materially affect our business, financial condition or future results. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

Our business depends on hydrocarbon supply and demand fundamentals, which can be adversely affected by numerous factors outside of our control, including the widespread outbreak of an illness, pandemic (like COVID-19) or any other public health crisis as well as actions taken by oil producers.

Our success depends on the demand for petroleum products such as transportation fuels and finished lubricant products, which is largely driven by the conditions of local and worldwide economies, and the supply of crude oil and other feedstocks. COVID-19’s spread across the globe and governmental actions in response thereto have negatively affected worldwide economic and commercial activity, reduced global demand for oil, gas and refined products, and created significant volatility and disruption of financial and commodity markets. Other factors currently impacting crude oil supply include production levels implemented by OPEC members, other large oil producers such as Russia and domestic and Canadian oil producers. The oversupply of crude oil in the market has caused certain domestic and Canadian oil producers from whom we source crude oil to shut-in their production, which could impact our ability to readily source crude oil once the stored crude oil is depleted. While there has been a recent stabilization in demand for refined products in the second quarter of 2020, this combination of events has contributed to an overall drop in prices for crude oil and refined products in the first half of 2020. In addition, the supply and demand for refined and finished lubricant products will depend on many other factors outside of our control, some of which include:

changes in domestic and international demand for, and the marketability of, our refined and finished lubricant products due to governmental actions, including travel bans and restrictions, quarantines, shelter in place orders, and shutdowns, which could result in a full or partial shutdown of our facilities;

increased price volatility, including the price we receive for refined and finished lubricant products;

the health of our workforce, including contractors and subcontractors, and their access to our facilities, which could result in a full or partial shutdown of our facilities if a significant portion of the workforce at a facility is impacted;

the ability or willingness of our vendors and suppliers to provide the equipment, parts, crude oil or other raw materials for our operations or otherwise fulfill their contractual obligations, which could reduce our production levels or otherwise cause our delay or failure to deliver refined or other finished lubricant products timely or at all or cause delay or failure to complete projects at our facilities;

•
the ability or willingness of our customers to fulfill their contractual obligations or any material reduction in, or loss of, revenue from our customers;

increased potential for the occurrence of operational hazards, including terrorism, cyberattacks or domestic vandalism, as well as information system failures or communication network disruptions;

increased cost and reduced availability of capital for growth or capital expenditures;

availability and operability of terminals, tankage and pipelines that store and transport crude oil and refined and finished lubricant products;

delay by government authorities in issuing or maintaining permits necessary for our business or our capital projects;

shareholder activism and activities by non-governmental organizations to limit sources of funding for the energy sector;
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increased costs of operation in relation to the COVID-19 outbreak, which costs may not be fully recoverable or adequately covered by insurance; and

•
the impact of any economic downturn, recession or other disruption of the U.S. and global economies and financial and commodity markets.

The spread of COVID-19 has caused us to significantly modify our business practices (including limiting employee and contractor presence at our work locations, restricting travel unless approved by senior leadership, quarantining employees when necessary, reducing our expected total consolidated capital expenditures for 2020 and reducing utilization at our refineries), and we may take further actions as may be required by government authorities or that we determine are in the best interests of our employees, contractors, customers, suppliers and communities. There is no certainty that such measures will be sufficient to mitigate the risks posed by the virus, and our ability to perform critical functions could be adversely impacted. In addition, a reasonable expectation exists that further deterioration in gross margins or a prolonged economic slowdown due to the COVID-19 pandemic could result in an additional impairment of assets or of goodwill at some point in the future. Such impairment charges could be material.

As the potential effects of COVID-19 are difficult to predict, the duration of any potential business disruption or the extent to which it may negatively affect our operating results is uncertain. Any potential impact will depend on future developments and new information that may emerge regarding the spread, severity and duration of the COVID-19 pandemic and the actions taken by authorities to contain it or manage its impact, all of which are beyond our control. In addition, if the volatility and seasonality in the oil and gas industry were to increase, the demand for our products and the prices that we will be able to charge for those products may decline. We are monitoring the situation to assess further possible implications to our business and to take actions in an effort to mitigate adverse consequences. These potential effects, while uncertain, could adversely affect our business, financial condition, results of operations and/or cash flows, as well as our ability to pay dividends to our shareholders.


Item 2.Unregistered Sales of Equity Securities and Use of Proceeds

(c) Common Stock Repurchases Made in the Quarter

Under our common stock repurchase programs, repurchases are being made from time to time in the open market or privately negotiated transactions based on market conditions, securities law limitations and other factors. The following table includes repurchases made under these programs during the thirdsecond quarter of 2019.2020.

Period 
Total Number of
Shares Purchased
 
Average Price
Paid per Share
 
Total Number of
Shares Purchased
as Part of Publicly Announced Plans or Programs
 
Maximum Dollar
Value of Shares
that May Yet Be
Purchased Under the Plans or Programs
July 2019 1,258,100
 $47.94
 1,258,100
 $448,563,068
August 2019 1,449,882
 $46.50
 1,449,882
 $381,139,885
September 2019 1,328,000
 $51.15
 1,328,000
 $313,216,174
Total for July to September 2019 4,035,982
   4,035,982
  
Period 
Total Number of
Shares Purchased
 
Average Price
Paid per Share
 
Total Number of
Shares Purchased
as Part of Publicly Announced Plans or Programs
 
Maximum Dollar
Value of Shares
that May Yet Be
Purchased Under the Plans or Programs
April 2020 —
 $—
 —
 $1,000,000,000
May 2020 —
 $—
 —
 $1,000,000,000
June 2020 —
 $—
 —
 $1,000,000,000
Total for April to June 2020 —
   —
  


Item 6.Exhibits

The Exhibit Index on page 6362 of this Quarterly Report on Form 10-Q lists the exhibits that are filed or furnished, as applicable, as part of the Quarterly Report on Form 10-Q.

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Exhibit Index

Exhibit Number  Description
   
3.1 
Amended and Restated Certificate of Incorporation of HollyFrontier Corporation (incorporated by reference to Exhibit 3.1 of Registrant’s Current Report on Form 8-K filed July 8, 2011, File No. 1-03876).
   
3.2 
Amended and Restated By-Laws of HollyFrontier Corporation (incorporated by reference to Exhibit 3.1 of Registrant’s Current Report on Form 8-K filed February 20, 2014, File No. 1-03876).
   
10.110.1*+ Fifth
Amended and Restated Master ThroughputConsulting Agreement and Release, dated as of July 1, 2019,June 30, 2020, by and between HollyFrontier RefiningCorporation, HollyFrontier Payroll Services, Inc. and Marketing LLC and Holly Energy Partners - Operating, L.P.James Stump.
10.2+HollyFrontier Corporation 2020 Long Term Incentive Plan (incorporated by reference to Exhibit 10.1 of Registrant’s Current Report on Form 8-K Current Report filed July 2, 2019,May 15, 2020, File No. 1-03876).
   
10.210.3+ Sixth
HollyFrontier Corporation 2020 Long Term Incentive Plan Sub-Plan for U.K. Employees (incorporated by reference to Exhibit 4.4 of Registrant’s Registration Statement on Form S-8 filed June 1, 2020, File No. 333-238835)

10.4*
Second Amendment to Third Amended and Restated Master ThroughputCrude Pipelines and Tankage Agreement dated as of October 2, 2019,May 26, 2020, by and betweenamong HollyFrontier Navajo Refining LLC, HollyFrontier Woods Cross Refining LLC, HollyFrontier Refining & Marketing LLC, and Holly Energy Partners -Operating,- Operating, L.P., HEP Pipeline, L.L.C. and HEP Woods Cross, L.L.C.
10.5*
First Amendment to Fifth Amended and Restated Master Lease and Access Agreement dated as of August 4, 2020, effective as of January 23, 2020, by and among certain subsidiaries of Holly Energy Partners, L.P. and certain subsidiaries of HollyFrontier Corporation.
10.6+Form of Restricted Stock Unit Agreement (for employees) (incorporated by reference to Exhibit 10.110.2 of Registrant’s Quarterly Report on Form 8-K Current Report filed October 3, 2019,10-Q for the quarterly period ended March 31, 2020, File No. 1-03876).
   
10.310.7+ Twentieth Amended and Restated OmnibusForm of Performance Share Unit Agreement dated as of October 2, 2019, by and between HollyFrontier Corporation, Holly Energy Partners, L.P. and certain of their respective subsidiaries (incorporated by reference to Exhibit 10.210.3 of Registrant’s Quarterly Report on Form 8-K Current Report filed October 3, 2019,10-Q for the quarterly period ended March 31, 2020, File No. 1-03876).
   
31.1* 
Certification of Chief Executive Officer under Section 302 of the Sarbanes-Oxley Act of 2002.
   
31.2* 
Certification of Chief Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.
   
32.1** 
Certification of Chief Executive Officer under Section 906 of the Sarbanes-Oxley Act of 2002.
   
32.2** 
Certification of Chief Financial Officer under Section 906 of the Sarbanes-Oxley Act of 2002.
   
101101++ 
The following financial information from HollyFrontier Corporation’s Quarterly Report on Form 10-Q for the quarter ended SeptemberJune 30, 2019,2020, formatted as inline XBRL (Inline Extensible Business Reporting Language): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Income, (iii) Consolidated Statements of Comprehensive Income, (iv) Consolidated Statements of Cash Flows, and (v) Notes to the Consolidated Financial Statements. The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.

   
104 Cover page Interactive Data File (formatted as inline XBRL and contained in exhibit 101).

* Filed herewith.
** Furnished herewith.
+ Constitutes management contracts or compensatory plans or arrangements.
++Filed electronically herewith.

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SIGNATURES

Pursuant to the requirements of the Securities and Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
    
  HOLLYFRONTIER CORPORATION
  (Registrant)
    
Date: October 31, 2019August 6, 2020  /s/ Richard L. Voliva III
   Richard L.Voliva III
   
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer)
    
Date: October 31, 2019August 6, 2020  /s/ J. W. Gann, Jr.Indira Agarwal
   J. W. Gann, Jr.Indira Agarwal
   
Vice President, Controller and
Chief Accounting Officer
(Principal Accounting Officer)

63