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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2020
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)
Delaware75-1056913
(State or other jurisdiction of incorporation or organization)(I.R.S. Employer Identification No.)
2828 N. Harwood, Suite 1300
Dallas
Texas75201
(Address of principal executive offices)(Zip Code)
(214) 871-3555
Registrant’s telephone number, including area code
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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 if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes  ☒    No  ☐
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15 (d) of the Act. Yes  ¨    No ☒
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.     Yes  ☒   No ☐
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate web site, if any, every Interactive Data File required to be submitted 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 filerAccelerated filerNon-accelerated filerSmaller 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 has filed a report on and attestation to its management's assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C.7262(b)) by the registered public accounting firm that prepared or issued its audit report. 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).     Yes   No  ☒
On June 30, 2020, the last business day of the registrant's most recently completed second fiscal quarter, the aggregate market value of the Common Stock, par value $0.01 per share, held by non-affiliates of the registrant was approximately $4.3 billion, based upon the closing price on the New York Stock Exchange on such date. (This is not deemed an admission that any person whose shares were not included in the computation of the amount set forth in the preceding sentence necessarily is an “affiliate” of the registrant.)
162,414,838 shares of Common Stock, par value $.01 per share, were outstanding on February 16, 2021.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant's proxy statement for its annual meeting of stockholders to be held on May 12, 2021, which proxy statement will be filed with the Securities and Exchange Commission within 120 days after December 31, 2020, are incorporated by reference in Part III.


Table of Content
TABLE OF CONTENTS


Item
Page
PART I
PART II
PART III
PART IV
Signatures

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PART I

FORWARD-LOOKING STATEMENTS

This Annual Report on Form 10‑K 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-K, including, but not limited to, those under “Business and Properties” in Items 1 and 2, “Risk Factors” in Item 1A, “Legal Proceedings” in Item 3 and “Management's Discussion and Analysis of Financial Condition and Results of Operations” in Item 7, 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 a significant 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 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, whether due to infection in the workforce or in response to reductions in demand;
the effects of current and future governmental and environmental regulations and policies, including the effects of current and future 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, 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 cyberattacks and the consequences of any such attacks;
general economic conditions, including uncertainty regarding the timing, pace and extent of an economic recovery in the United States;
continued 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-K, including without limitation the forward-looking statements that are referred to above. You should not put any undue reliance on any forward-looking statements. When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements set forth in this Form 10-K under “Risk Factors” in Item 1A and in conjunction with the discussion in this Form 10-K in “Management's Discussion and Analysis of Financial Condition and Results of Operations” under the heading “Liquidity and Capital Resources.” All forward-looking statements included in this Form 10-K 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:
“Alkylation” means the reaction of propylene or butylene (olefins) with isobutane to form an iso-paraffinic gasoline (inverse of cracking).

“Aromatic oil” is long chain oil that is highly aromatic in nature and is used to manufacture tires and industrial rubber products and in the production of specialty asphalt.

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.

“Biodiesel” means a clean alternative fuel produced from renewable biological resources.

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.

“Catalytic reforming” means a refinery process which uses a precious metal (such as platinum) based catalyst to convert low octane naphtha to high octane gasoline blendstock and hydrogen. The hydrogen produced from the reforming process is used to desulfurize other refinery oils and is a primary source of hydrogen for the refinery.
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.

Ethanol” means a high octane gasoline blend stock that is used to make various grades of gasoline.

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.

Gas oil” is a group of petroleum distillation products having boiling points between kerosene and lubricating oil and is used as fuel in construction and agricultural machinery.

Hydrodesulfurization” means to remove sulfur and nitrogen compounds from oil or gas in the presence of hydrogen and a catalyst at relatively high temperatures.

Hydrogen plant” means a refinery unit that converts natural gas and steam to high purity hydrogen, which is then used in the hydrodesulfurization, hydrocracking and isomerization processes.

“HF alkylation” or hydrofluoric alkylation, means a refinery process which combines isobutane and C3/C4 olefins using HF acid as a catalyst to make high octane gasoline blend stock.
Isomerization” means a refinery process for rearranging the structure of C5/C6 molecules without changing their size or chemical composition and is used to improve the octane of C5/C6 gasoline blendstocks.

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.

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“MSAT2” means Control of Hazardous Air Pollutants from Mobile Sources, a rule issued by the U.S. Environmental Protection Agency to reduce hazardous emissions from motor vehicles and motor vehicle fuels.

“MEK” means a lube process that separates waxy oil from non-waxy oils using methyl ethyl ketone as a solvent.

MMBTU” means one million British thermal units.

“Natural gasoline” means a low octane gasoline blend stock that is purchased and used to blend with other high octane stocks produced to make various grades of gasoline.

“Paraffinic oil” is a high paraffinic, high gravity oil produced by extracting aromatic oils and waxes from gas oil and is used in producing high-grade lubricating oils.

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.

“Reforming” means the process of converting gasoline type molecules into aromatic, higher octane gasoline blend stocks while producing hydrogen in the process.

Renewable diesel” means a diesel fuel derived from vegetable oils or animal fats that is produced through various processes, most commonly through hydrotreating, reacting the feedstock with hydrogen under temperatures and pressure in the presence of a catalyst.

“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.

“Roofing flux” is produced from the bottom cut of crude oil and is the base oil used to make roofing shingles for the housing industry.

“ROSE,” or “Solvent deasphalter / residuum oil supercritical extraction,” means a refinery unit that uses a light hydrocarbon like propane or butane to extract non-asphaltene heavy oils from asphalt or atmospheric reduced crude. These deasphalted oils are then further converted to gasoline and diesel in the FCC process. The remaining asphaltenes are either sold, blended to fuel oil or blended with other asphalt as a hardener.

“Scanfiner” is a refinery unit that removes sulfur from gasoline to produce low sulfur gasoline blendstock.

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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Items 1 and 2. Business and Properties


COMPANY OVERVIEW

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 Annual Report on Form 10-K 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.

We are principally an independent petroleum refiner that produces high-value light products such as gasoline, diesel fuel, jet fuel, specialty lubricant products, and specialty and modified asphalt. We were incorporated in Delaware in 1947 and maintain our principal corporate offices at 2828 N. Harwood, Suite 1300, Dallas, Texas 75201-1507. Our telephone number is 214-871-3555, and our internet website address is www.hollyfrontier.com. The information contained on our website does not constitute part of this Annual Report on Form 10-K. A print copy of this Annual Report on Form 10-K will be provided without charge upon written request to the Vice President, Investor Relations at the above address. A direct link to our SEC filings is available on our website under the Investor Relations tab. Also available on our website are copies of our Corporate Governance Guidelines, Audit Committee Charter, Compensation Committee Charter, Nominating / Corporate Governance Committee Charter, Environmental, Health, Safety, and Public Policy Committee Charter and Code of Business Conduct and Ethics, all of which will be provided without charge upon written request to the Vice President, Investor Relations at the above address. Our Code of Business Conduct and Ethics applies to all of our officers, employees and directors, including our principal executive officer, principal financial officer and principal accounting officer. Our common stock is traded on the New York Stock Exchange under the trading symbol “HFC.”

In November 2019, we announced our plans to construct a new renewable diesel unit (“RDU”) at our Artesia facility. The RDU will have a production capacity of approximately 120 million gallons a year and allow us to process soybean oil and other renewable feedstocks into renewable diesel. This investment will provide us the opportunity to meet the demand for low-carbon fuels while covering the cost of our annual RINs purchase obligation under current market conditions.

In the third quarter of 2020, we permanently ceased petroleum refining operations at our Cheyenne Refinery and subsequently began converting certain assets at our Cheyenne Refinery to renewable diesel production. The Cheyenne RDU will have a production capacity of approximately 90 million gallons a year. This decision was primarily based on a positive outlook in 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.

Additionally, we are constructing a pre-treatment unit (“PTU”) at our Artesia facility that will provide feedstock flexibility for both our Artesia and Cheyenne RDUs. The RDUs and PTU, along with corresponding rail infrastructure and storage tanks, are estimated to have a total capital cost of $650 million to $750 million. The RDUs are expected to be completed in the first quarter of 2022 and the PTU in the first half of 2022.

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 of the largest suppliers of locomotive engine oil in North America and is headquartered in Council Bluffs, Iowa.

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On October 29, 2016, we entered into a share purchase agreement with Suncor Energy Inc. (“Suncor”) to acquire 100% of the outstanding capital stock of Petro-Canada Lubricants Inc. (“PCLI”). The acquisition closed on February 1, 2017. Cash consideration paid was $862.1 million, or $1.125 billion Canadian dollars. PCLI, located in Mississauga, Ontario, is the largest producer of base oils in Canada with a plant having 15,600 BPD of lubricant production capacity and is one of the largest manufacturers of high margin Group III base oils in North America.

As of December 31, 2020, we:
owned and operated a petroleum refinery in El Dorado, Kansas (the “El Dorado Refinery”), two 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”) and a refinery in Woods Cross, Utah (the “Woods Cross Refinery”);
owned a facility in Cheyenne, Wyoming, which operated as a petroleum refinery until early August 2020, at which time its assets began to be converted to renewable diesel production (the “Cheyenne Refinery”);
owned and operated PCLI located in Mississauga, Ontario, which produces base oils and other specialized lubricant products;
owned and operated Sonneborn with manufacturing facilities in Petrolia, Pennsylvania and the Netherlands, which produce specialty lubricant products such as white oils, petrolatums and waxes;
owned and operated Red Giant Oil, which supplies locomotive engine oil and has storage and distribution facilities in Iowa 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. 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 geographic regions of the United States.

HEP is a variable interest entity (“VIE”) as defined under U.S. generally accepted accounting principles (“GAAP”). Information on HEP's assets and acquisitions completed in the past three years can be found under the “Holly Energy Partners, L.P.” section provided later in this discussion of Items 1 and 2, “Business and Properties.”

Our operations are currently organized into three reportable segments, Refining, Lubricants and Specialty Products and HEP. The Refining segment includes the operations of our El Dorado, Tulsa, Navajo and Woods Cross Refineries and HFC Asphalt. The Lubricants and Specialty Products segment includes the operations of our Petro-Canada Lubricants business, Red Giant Oil and Sonneborn in addition to specialty lubricant products produced at our Tulsa Refinery. The HEP segment involves all of the operations of HEP. See Note 20 “Segment Information” in the Notes to Consolidated Financial Statements for additional information on our reportable segments.


REFINERY OPERATIONS

Our refinery operations serve the Mid-Continent, Southwest and Rocky Mountain geographic regions of the United States. We own and operate four complex refineries having a combined crude oil processing capacity of 405,000 barrels per stream day. Each of our refineries has the complexity to convert discounted, heavy and sour crude oils into a high percentage of gasoline, diesel and other high-value refined products.

The tables presented below and elsewhere in this discussion of our refinery operations set forth information, including non-GAAP performance measures, about our 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 7A of Part II of this Form 10-K.

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As of December 31, 2020, our refinery operations included the El Dorado, Tulsa, Navajo and Woods Cross Refineries. In the third quarter of 2020, we permanently ceased petroleum refining operations at our Cheyenne Refinery and subsequently began converting certain assets at our Cheyenne Refinery to renewable diesel production. The disaggregation of our refining geographic operating data is presented in two regions, Mid-Continent and West, to best reflect the economic drivers of our refining operations. The Mid-Continent region will continue to be comprised of the El Dorado and Tulsa Refineries, and the new West region will be comprised of the Navajo and Woods Cross Refineries. All prior period geographic operating data included below has been retrospectively adjusted to reflect the revised regional groupings.
Years Ended December 31,
202020192018
Consolidated
Crude charge (BPD) (1)
365,190 388,860 384,380 
Refinery throughput (BPD) (2)
395,080 417,570 413,780 
Sales of produced refined products (BPD) (3)
391,670 414,370 408,390 
Refinery utilization (4)
90.2 %96.0 %94.9 %
Average per produced barrel sold (5)
Refinery gross margin$7.29 $15.92 $16.50 
Refinery operating expenses (6)
6.05 6.12 6.06 
Net operating margin$1.24 $9.80 $10.44 
Refinery operating expenses per throughput barrel (7)
$6.00 $6.07 $5.98 
Feedstocks:
Sweet crude oil48 %45 %44 %
Sour crude oil29 %34 %35 %
Heavy sour crude oil11 %10 %10 %
Black wax crude oil%%%
Other feedstocks and blends%%%
Total100 %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 405,000 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 7A of Part II of this Form 10-K.
(6)Represents total Mid-Continent and West regions operating expenses, exclusive of long-lived asset impairment charges and depreciation and amortization, divided by sales volumes of refined products produced at our refineries.
(7)Represents total Mid-Continent and West regions operating expenses, exclusive of long-lived asset impairment charges and depreciation and amortization, divided by refinery throughput.

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Products and Customers
Set forth below is information regarding refined product sales:
Years Ended December 31,
202020192018
Consolidated
Sales of refined products:
Gasolines54 %52 %52 %
Diesel fuels34 %34 %34 %
Jet fuels%%%
Fuel oil%%%
Asphalt%%%
Base oils%%%
LPG and other%%%
Total100 %100 %100 %

Light products are shipped to customers via product pipelines or are available for loading at our refinery truck facilities and terminals. Light products are also made available to customers at various other locations via exchange with other parties.

Our principal customers for gasoline include other refiners, convenience store chains, independent marketers and retailers. Diesel fuel is sold to other refiners, truck stop chains, wholesalers and railroads. Jet fuel is sold for commercial airline use. Base oils are intercompany sales to our Lubricants and Specialty Products segment. LPG's are sold to LPG wholesalers and LPG retailers. We produce and purchase asphalt products that are sold to governmental entities, paving contractors or manufacturers. Asphalt is also blended into fuel oil and is either sold locally or is shipped to the Gulf Coast. See Note 5 “Revenues” in the Notes to Consolidated Financial Statements for additional information on our significant customers.


Mid-Continent Region (El Dorado and Tulsa Refineries)

Facilities
The El Dorado Refinery is a high-complexity coking refinery with a 135,000 barrels per stream day processing capacity and the ability to process significant volumes of heavy and sour crudes. The integrated refining processes at the Tulsa West and East refinery facilities provide us with a highly complex refining operation having a combined crude processing rate of approximately 125,000 barrels per stream day.

The following table sets forth information about our Mid-Continent region operations, including non-GAAP performance measures.
Years Ended December 31,
202020192018
Mid-Continent Region (El Dorado and Tulsa Refineries)
Crude charge (BPD) (1)
241,140 254,010 249,240 
Refinery throughput (BPD) (2)
257,030 268,500 264,730 
Sales of produced refined products (BPD) (3)
248,320 259,310 255,800 
Refinery utilization (4)
92.7 %97.7 %95.9 %
Average per produced barrel sold (5)
Refinery gross margin$5.17 $13.71 $14.44 
Refinery operating expenses (6)
5.46 5.77 5.51 
Net operating margin$(0.29)$7.94 $8.93 
Refinery operating expenses per throughput barrel (7)
$5.27 $5.58 $5.33 

Footnote references are provided under our Consolidated Refinery Operating Data table on page 8.

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Years Ended December 31,
202020192018
Mid-Continent Region (El Dorado and Tulsa Refineries)
Feedstocks:
Sweet crude oil58 %55 %54 %
Sour crude oil19 %24 %24 %
Heavy sour crude oil17 %16 %16 %
Other feedstocks and blends%%%
Total100 %100 %100 %

The El Dorado Refinery is located on 1,100 acres south of El Dorado, Kansas and is a fully integrated refinery. The principal processing units at the El Dorado Refinery consist of crude and vacuum distillation; hydrodesulfurization of naphtha, kerosene, diesel, and gas oil streams; isomerization; catalytic reforming; aromatics recovery; catalytic cracking; alkylation; delayed coking; hydrogen production; and sulfur recovery.

The Tulsa West facility is located on a 750-acre site in Tulsa, Oklahoma situated along the Arkansas River. The principal processing units at the Tulsa West facility consist of crude and vacuum distillation (with light ends recovery), naphtha hydrodesulfurization, propane de-asphalting, lubes extraction, MEK dewaxing, delayed coker and butane splitter units.

The Tulsa East facility is located on a 466-acre site also in Tulsa, Oklahoma situated along the Arkansas River. The principal processing units at the Tulsa East facility consist of crude and vacuum distillation, naphtha hydrodesulfurization, FCC, isomerization, catalytic reforming, alkylation, scanfiner, diesel hydrodesulfurization and sulfur units.

Markets and Competition
The primary markets for the El Dorado Refinery's refined products are Colorado and the Plains States, which include the Kansas City metropolitan area. The gasoline, diesel and jet fuel produced by the El Dorado Refinery are primarily shipped via pipeline to terminals for distribution by truck or rail. We ship product via the NuStar Pipeline Operating Partnership L.P. Pipeline to the northern Plains States, via the Magellan Pipeline Company, L.P. (“Magellan”) mountain pipeline to Denver, Colorado, and on the Magellan mid-continent pipeline to the Plains States. Additionally, HEP's on-site truck and rail racks facilitate access to local refined product markets.

The El Dorado Refinery faces competition from other Plains States and Mid-Continent refiners, but the principal competitors for the El Dorado Refinery are Gulf Coast refiners. Our Gulf Coast competitors typically have lower production costs due to greater economies of scale; however, they incur higher refined product transportation costs, which allows the El Dorado Refinery to compete effectively in the Plains States and Rocky Mountain region with Gulf Coast refineries.

The Tulsa Refineries serve the Mid-Continent geographic region of the United States. Distillates and gasolines are primarily delivered from the Tulsa Refineries to market via pipelines owned and operated by Magellan. These pipelines connect the refinery to distribution channels throughout Colorado, Oklahoma, Kansas, Missouri, Illinois, Iowa, Minnesota, Nebraska and Arkansas. Additionally, HEP's on-site truck and rail racks facilitate access to local refined product markets.

The Tulsa Refineries’ principal customers for conventional gasoline include other refiners, convenience store chains, independent marketers and retailers. Truck stop operators and railroads are the primary diesel customers. Jet fuel is sold primarily for commercial use. The refinery's asphalt and roofing flux products are sold via truck or railcar directly from the refineries or to customers throughout the Mid-Continent geographic region primarily to paving contractors and manufacturers of roofing products.

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Products
Set forth below is information regarding refined product sales attributable to our Mid-Continent region:
Years Ended December 31,
202020192018
Mid-Continent Region (El Dorado and Tulsa Refineries)
Sales of refined products:
Gasolines52 %51 %51 %
Diesel fuels34 %32 %33 %
Jet fuels%%%
Fuel oil%%%
Asphalt%%%
Base oils%%%
LPG and other%%%
Total100 %100 %100 %

Crude Oil and Feedstock Supplies
Both of our Mid-Continent Refineries are connected via pipeline to Cushing, Oklahoma, a significant crude oil pipeline trading and storage hub. The El Dorado Refinery and the Tulsa Refineries are located approximately 125 miles and 50 miles, respectively, from Cushing, Oklahoma. Local pipelines provide direct access to regional Oklahoma crude production as well as access to United States onshore and Canadian crudes. The proximity of the refineries to the Cushing pipeline and storage hub provides the flexibility to optimize their crude slate with a wide variety of crude oil supply options. Additionally, we have transportation service agreements to transport Canadian crude oil on the Spearhead and Keystone Pipelines, enabling us to transport Canadian crude oil to Cushing for subsequent shipment to either of our Mid-Continent Refineries.

We also purchase isobutane, natural gasoline, butane and other feedstocks for processing at our Mid-Continent Refineries. The El Dorado Refinery is connected to Conway, Kansas, a major gas liquids trading and storage hub, via the Oneok Pipeline. From time to time, other feedstocks such gas oil, naphtha and light cycle oil are purchased from other refiners for use at our refineries.


West Region (Navajo and Woods Cross Refineries)

Facilities
The Navajo Refinery has a crude oil processing capacity of 100,000 barrels per stream day and has the ability to process sour crude oils into high-value light products such as gasoline, diesel fuel and jet fuel.

The Woods Cross Refinery has a crude oil processing capacity of 45,000 barrels per stream day and processes regional sweet and black wax crude into high-value light products.

The following table sets forth information about our West region operations, including non-GAAP performance measures.
Years Ended December 31,
202020192018
West Region (Navajo and Woods Cross Refineries)
Crude charge (BPD) (1)
124,050 134,850 135,140 
Refinery throughput (BPD) (2)
138,050 149,070 149,050 
Sales of produced refined products (BPD) (3)
143,350 155,060 152,590 
Refinery utilization (4)
85.6 %93.0 %93.2 %
Average per produced barrel sold (5)
Refinery gross margin$10.97 $19.62 $19.96 
Refinery operating expenses (6)
7.07 6.69 6.99 
Net operating margin$3.90 $12.93 $12.97 
Refinery operating expenses per throughput barrel (7)
$7.34 $6.96 $7.15 

Footnote references are provided under our Consolidated Refinery Operating Data table on page 8.

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Years Ended December 31,
202020192018
West Region (Navajo and Woods Cross Refineries)
Feedstocks:
Sweet crude oil30 %26 %27 %
Sour crude oil49 %52 %52 %
Black wax crude oil11 %12 %12 %
Other feedstocks and blends10 %10 %%
Total100 %100 %100 %

The Navajo Refinery's Artesia, New Mexico facility is located on a 561-acre site and is a fully integrated refinery with crude distillation, vacuum distillation, FCC, ROSE (solvent deasphalter), HF alkylation, catalytic reforming, hydrodesulfurization, mild hydrocracking, isomerization, sulfur recovery and product blending units.

The Artesia facility is operated in conjunction with a refining facility located in Lovington, New Mexico, approximately 65 miles east of Artesia. The principal equipment at the Lovington facility consists of a crude distillation unit and associated vacuum distillation units. The Lovington facility processes crude oil into intermediate products that are transported to Artesia by means of three intermediate pipelines owned by HEP. These products are then upgraded into finished products at the Artesia facility. The combined crude oil capacity of the Navajo Refinery facilities is 100,000 BPSD and it typically processes or blends an additional 10,000 BPSD of natural gasoline, butane, gas oil and naphtha.

The Woods Cross Refinery facility is located on a 200-acre site and is a fully integrated refinery with crude distillation, solvent deasphalter, FCC, HF alkylation, catalytic reforming, hydrodesulfurization, isomerization, sulfur recovery and product blending units. The facility typically processes or blends an additional 2,000 BPSD of natural gasoline, butane and gas oil over its 45,000 BPSD capacity.

Markets and Competition
The Navajo Refinery primarily serves the southwestern United States market, including the metropolitan areas of El Paso, Texas; Albuquerque, Moriarty and Bloomfield, New Mexico; Phoenix and Tucson, Arizona; and portions of northern Mexico. Our products are shipped through HEP's pipelines from Artesia, New Mexico to El Paso, Texas and from El Paso to Albuquerque and to Mexico via products pipeline systems owned by Magellan and from El Paso to Tucson and Phoenix via a products pipeline system owned by Kinder Morgan's subsidiary, SFPP, L.P. (“SFPP”). In addition, petroleum products from the Navajo Refinery are transported to markets in northwest New Mexico, to Moriarty, New Mexico, near Albuquerque, via HEP's pipelines running from Artesia to San Juan County, New Mexico, and to Bloomfield, New Mexico. We have refined product storage through our pipelines and terminals agreement with HEP at terminals in Artesia and Moriarty, New Mexico.

The Woods Cross Refinery's primary market is Utah, which is currently supplied by a number of local refiners and the Pioneer Pipeline. It also supplies a small percentage of the refined products consumed in the combined Idaho, Wyoming, eastern Washington and Nevada markets. Our Woods Cross Refinery ships refined products over a common carrier pipeline system owned by Andeavor Logistics Northwest Pipelines LLC to numerous terminals, including HEP's terminal at Spokane, Washington and to third-party terminals at Pocatello and Boise, Idaho and Pasco, Washington as well as to Cedar City, Utah and Las Vegas, Nevada via the UNEV Pipeline.

Products
Set forth below is information regarding refined product sales attributable to our West region:
Years Ended December 31,
202020192018
West Region (Navajo and Woods Cross Refineries)
Sales of refined products:
Gasolines56 %53 %53 %
Diesel fuels35 %37 %38 %
Fuel oil%%%
Asphalt%%%
LPG and other%%%
Total100 %100 %100 %

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Crude Oil and Feedstock Supplies
The Navajo Refinery is situated near the Permian Basin, an area that has historically, and continues to have, abundant supplies of crude oil available both for regional users and for export to other areas. We purchase crude oil from independent producers in southeastern New Mexico and west Texas as well as from major oil companies. The crude oil is gathered through HEP's pipelines and through third-party tank trucks and crude oil pipeline systems for delivery to the Navajo Refinery.

We also purchase volumes of isobutane, natural gasoline and other feedstocks to supply the Navajo Refinery from sources in Texas and the Mid-Continent area that are delivered to our region on a common carrier pipeline owned by Enterprise Products, L.P. Ultimately all volumes of these products are shipped to the Artesia refining facilities on HEP's intermediate pipelines running from Lovington to Artesia. From time to time, we purchase gas oil, naphtha and light cycle oil from other refiners for use as feedstock.

The Woods Cross Refinery currently obtains crude oil from suppliers in Canada, Wyoming and Utah as delivered via common carrier pipelines, including the SLC Pipeline and Frontier Pipeline owned by HEP. Supplies of black wax crude oil are shipped via truck.


HollyFrontier Asphalt Company

We manufacture commodity and modified asphalt products at our manufacturing facilities located in Glendale, Arizona; Albuquerque, New Mexico; Artesia, New Mexico and Catoosa, Oklahoma. Our Albuquerque and Artesia facilities manufacture modified hot asphalt products and commodity and modified asphalt emulsions from base asphalt materials provided by our refineries and third-party suppliers. Our Glendale facility manufactures modified hot asphalt products from base asphalt materials provided by our refineries and third-party suppliers. Our Catoosa facility manufactures specialty modified asphalt and commodity asphalt products. We market these asphalt products in Arizona, California, Colorado, New Mexico, Oklahoma, Kansas, Missouri, Texas, Arkansas and northern Mexico. Our products are shipped via third-party trucking companies to commercial customers that provide asphalt based materials for commercial and government projects.


LUBRICANTS AND SPECIALTY PRODUCTS OPERATIONS

Our lubricants and specialty products operations consist of our Petro-Canada Lubricants, Red Giant Oil, Sonneborn and the Tulsa rack forward businesses.

Our Petro-Canada Lubricants business produces automotive, industrial and food grade lubricants and greases, base and process oils and specialty fluids. It is one of the largest manufacturers of high margin Group III base oils in North America. Products are marketed in over 80 countries worldwide to a diverse customer base through a global sales force and distributor network.

Our Red Giant Oil business provides high quality lubricants to the railroad industry, which represents a market of a small number of high-value customers who associate the Red Giant Oil name with a niche suite of products.

Sonneborn is a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes for the personal care, cosmetic, pharmaceutical and food processing industries. Combined with Petro-Canada Lubricants, it is one of the world's largest producers of pharmaceutical white oils.

Our Tulsa Refinery produces high quality base oils, process oils, waxes, horticultural oils and asphalt performance products. Products are marketed worldwide through strategically located terminals in the United States and selected distributors internationally.

The following table sets forth information about our lubricants and specialty products operations and includes Red Giant Oil for the period August 1, 2018 (date of acquisition) through December 31, 2020, and Sonneborn for the period February 1, 2019 (date of acquisition) through December 31, 2020.
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Years Ended December 31,
202020192018
Lubricants and Specialty Products
Throughput (BPD)19,645 20,251 19,590 
Sales of produced refined products (BPD)32,902 34,827 30,510 
Sales of produced refined products:
Finished products49 %49 %48 %
Base oils26 %27 %31 %
Other25 %24 %21 %
Total100 %100 %100 %

PCLI owns and operates a production facility located in Mississauga, Ontario having lubricant production capacity of 15,600 BPD and has the flexibility to match unique lubricant product formulations. The primary operating units are high-pressure hydrotreating and hydrofinishing, solvent dewaxing and catalytic dewaxing. In addition, the facility operates a hydrogen plant, naphtha hydrotreater and catalytic reformer, along with other utility units to support production. The Mississauga plant also includes packaging facilities and has extensive distribution capabilities with marine, truck and rail access.

Red Giant Oil, headquartered in Council Bluffs, Iowa, owns and operates blending and distribution facilities in Council Bluffs, Iowa; Joshua, TX and Newcastle, Wyoming.

Sonneborn has manufacturing facilities in Petrolia, Pennsylvania and the Netherlands. The Sonneborn Petrolia site has a production capacity of 6,000 BPD with flexibility to produce a full range of finished specialty products. The primary operating unit is a high-pressure hydrotreater with hydrofinishing. In addition, the facility operates a hydrogen plant along with other utility units to support production. The Petrolia plant also includes packaging facilities with distribution capabilities through rail and trucking. The Sonneborn Netherlands sites include processing facilities in Amsterdam and Koog with a production capacity of approximately 1,500 BPD. The primary operating units include base oil acid treating, percolation filtration, and bleaching & steaming operations. The Netherlands sites include packaging facilities with distribution capabilities through truck and marine.


HOLLY ENERGY PARTNERS, L.P.

HEP is a Delaware limited partnership that trades on the New York Stock Exchange under the trading symbol “HEP.” 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, as well as other third-party refineries, in the Mid-Continent, Southwest and Rocky Mountain geographic regions of the United States. Additionally, HEP owns 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 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”), 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 pipeline under construction that will run from Cushing, Oklahoma to our Tulsa Refineries.

HEP generates revenues by charging tariffs for transporting petroleum products and crude oil through its pipelines, by charging fees for terminalling and storing refined products and other hydrocarbons and providing other services at its storage tanks, terminals and refinery processing units. HEP does not take ownership of products that it transports, terminals, stores or refines; therefore, it is not directly exposed to changes in commodity prices.

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Investment in Joint Venture

Cushing Connect Joint Venture
In October 2019, HEP Cushing LLC, a wholly-owned subsidiary of HEP, and Plains Marketing, L.P., a wholly-owned subsidiary of Plains All American Pipeline, L.P. (“Plains”), formed a 50/50 joint venture, Cushing Connect, for (i) the development, construction, ownership and operation of a new 160,000 barrel per day common carrier crude oil pipeline (the “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 “Cushing Connect Terminal”). The Cushing Connect Terminal was fully in service beginning in April 2020, and the Cushing Connect Pipeline is expected to be placed in service during the second quarter of 2021. Long-term commercial agreements have been entered into to support the Cushing Connect assets.

Cushing 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 Cushing Connect Terminal. The total investment in Cushing Connect will be shared proportionately among the partners, and HEP estimates its share of the cost of the Cushing Connect Terminal contributed by Plains and Cushing Connect Pipeline construction costs are approximately $65.0 million. However, any Cushing Connect Pipeline construction costs exceeding 10% of the budget are borne solely by HEP.

Transportation Agreements

Agreements with HEP
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 pipelines, 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 (“PPI”) or Federal Energy Regulatory Commission (“FERC”) index. As of December 31, 2020, these agreements required minimum annualized payments to HEP of $351.1 million. However, as previously disclosed, subsequent to year end these agreements were modified to account for the conversion of our Cheyenne Refinery to renewable diesel production, and as of January 1, 2021, require minimum annualized payments to HEP of $341.9 million.

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

As of December 31, 2020, HEP's assets included:

Pipelines
approximately 800 miles of refined product pipelines, including 340 miles of leased pipelines, that transport gasoline, diesel and jet fuel principally from our Navajo Refinery in New Mexico to our customers in the metropolitan and rural areas of Texas, New Mexico, Arizona, Colorado, Utah and northern Mexico;
approximately 510 miles of refined product pipelines that transport refined products from Delek's Big Spring refinery in Texas to its customers in Texas and Oklahoma;
two 65-mile pipelines that transport intermediate feedstocks and crude oil from our Navajo Refinery crude oil distillation and vacuum facilities in Lovington, New Mexico to our petroleum refinery facilities in Artesia, New Mexico;
one 65-mile intermediate pipeline that is used for the shipment of crude oil from the gathering systems in Barnsdall and Beeson, New Mexico to our Navajo Refinery;
the SLC Pipeline, a 95-mile intrastate crude oil pipeline system that transports crude oil into the Salt Lake City, Utah area from the Utah terminus of the Frontier Pipeline, as well as crude oil flowing from Wyoming and Utah via Plains Rocky Mountain Pipeline;
the Frontier Pipeline, a 289-mile crude oil pipeline running from Casper, Wyoming to Frontier Station, Utah through a connection to the SLC Pipeline;
approximately 940 miles of crude oil trunk, gathering and connection pipelines located in west Texas, New Mexico and Oklahoma that primarily deliver crude oil to our Navajo Refinery;
approximately 8 miles of refined product pipelines that support our Woods Cross Refinery located near Salt Lake City, Utah;
gasoline and diesel connecting pipelines that support our Tulsa East facility;
five intermediate product and gas pipelines between our Tulsa East and Tulsa West facilities;
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crude receiving assets located at our Cheyenne facility;
a 75% interest in the UNEV Pipeline, a 427-mile, 12-inch refined products pipeline running from Woods Cross, Utah to Las Vegas, Nevada;
a 50% interest in the Osage Pipeline, a 135-mile pipeline that transports crude oil from Cushing, Oklahoma to our El Dorado Refinery and also has a connection to the Jayhawk pipeline that services the CHS refinery in McPherson, Kansas;
a 50% interest in the Cheyenne Pipeline, an 87-mile crude oil pipeline running from Fort Laramie, Wyoming to Cheyenne, Wyoming; and
a 50% interest in Cushing Connect, a joint venture formed to construct a 160,000 BPD pipeline to connect the Cushing, Oklahoma crude oil hub to our Tulsa Refineries.

Refined Product Terminals and Refinery Tankage
three refined product terminals located in Orla, Texas and Moriarty and Bloomfield, New Mexico, with an aggregate capacity of approximately 458,000 barrels, that are integrated with HEP's refined product pipeline system that serves our Navajo Refinery;
one refined product terminal located in Spokane, Washington, with a capacity of approximately 420,000 barrels, that serves third-party common carrier pipelines;
one refined product terminal near Mountain Home, Idaho, with a capacity of 120,000 barrels, that serves a nearby United States Air Force Base;
two refined product terminals, located in Wichita Falls and Abilene, Texas, and one tank farm in Orla, Texas with aggregate capacity of approximately 600,000 barrels, that are integrated with HEP's refined product pipelines that serve Delek's Big Spring, Texas refinery;
a refined product terminal in Catoosa, Oklahoma that stores specialty lubricant products and is utilized by our Tulsa Refineries;
a refined product loading rack facility at each of our El Dorado, Tulsa, Navajo and Woods Cross Refineries and our Cheyenne facility, heavy product / asphalt loading rack facilities at our Tulsa East facility, Navajo Refinery Lovington facility and Cheyenne facility, LPG loading rack facilities at our El Dorado Refinery, Tulsa West facility and Cheyenne facility, lube oil loading racks at our Tulsa West facility and crude oil Leased Automatic Custody Transfer units located at our Cheyenne facility;
on-site crude oil tankage at our Tulsa, Navajo and Woods Cross Refineries and Cheyenne facility having an aggregate storage capacity of approximately 1,530,000 barrels;
on-site refined and intermediate product tankage at our El Dorado and Tulsa and Refineries and Cheyenne facility having an aggregate storage capacity of approximately 8,600,000 barrels;
eleven crude oil tanks adjacent to our El Dorado Refinery with a capacity of approximately 1,100,000 barrels that primarily serve our El Dorado Refinery;
crude oil tankage with an aggregate storage capacity of approximately 480,000 barrels that primarily serve our Navajo Refinery;
Frontier Pipeline's tankage with an aggregate capacity of approximately 380,000 barrels;
a 75% interest in UNEV Pipeline's product terminals near Cedar City, Utah and Las Vegas, Nevada with an aggregate capacity of approximately 660,000 barrels; and
a 50% interest in Cushing Connect's crude oil tankage with a capacity of approximately 1,500,000 barrels in Cushing, Oklahoma.

Refinery Processing Units
a naphtha fractionation tower at our El Dorado Refinery, with a capacity of 50,000 BPD of desulfurized naphtha;
a hydrogen generation unit at our El Dorado Refinery, with a capacity of 6.1 million standard cubic feet per day of natural gas.
a crude unit, which is primarily an atmospheric distillation tower, a desalter and heat exchangers, at our Woods Cross Refinery, with a feedstock capacity of 15,000 BPD of crude oil;
a FCC unit at our Woods Cross Refinery, which converts crude oil to high-value refined products such as gasoline, diesel and liquefied petroleum gases, with a capacity of 8,000 BPD; and
a polymerization unit at our Woods Cross Refinery, that uses the output of the fluid cracking unit and converts them into gasoline blendstock, with a capacity of 2,500 BPD.
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ADDITIONAL OPERATIONS AND OTHER INFORMATION

Corporate Offices
Our principal corporate offices are leased and located in Dallas, Texas. Functions performed in our Dallas office include overall corporate management, refinery and HEP management, planning and strategy, corporate finance, crude acquisition, logistics, contract administration, marketing, investor relations, governmental affairs, accounting, tax, treasury, information technology, legal and human resources support functions.

Human Capital
Our People
Our people differentiate us from our peers. Our “One HFC Culture” focuses on four key values – safety, integrity, teamwork and ownership. These values influence our decisions, shape our behaviors and provide the opportunity for our employees to thrive. Safety is our first priority. We care about our people and have implemented policies and procedures designed to help make sure they return home safely every day. We focus on integrity and doing the right thing. We champion a culture of teamwork and ownership by supporting each other and empowering employees to take action where they see a need or opportunity.

As of December 31, 2020, we had 3,891 employees located in the following geographies: 2,933 employees in the United States, 711 employees in Canada and 247 employees in Europe and Asia. As of December 31, 2020, 1,306 employees were covered by collective bargaining agreements with various expiration dates ranging between 2021 and 2024. We have experienced no material interruptions of operations due to disputes with our employees and management attempts to have and believes that we have positive working relationships with our local unions and their members.

Oversight
Our Board of Directors and Board committees provide oversight on our strategies and policies related to human capital management. Our Compensation Committee is responsible for periodically reviewing HollyFrontier’s strategies and policies regarding the promotion of employee diversity, equity and inclusion, talent and performance management, pay equity and employee engagement, as well as our executive succession planning. Our Nominating, Governance and Social Responsibility Committee oversees our policies and practices regarding human rights in our operations and supply chain. This high level oversight is designed to ensure that our actions are well aligned with our strategies in attracting, retaining and developing a workforce that aligns with our values and strategies.

Diversity & Inclusion
Our leadership is committed to attracting, retaining and developing a highly engaged, high-performing, diverse workforce and cultivating an inclusive workplace where all employees feel valued and have a sense of belonging. Increasing our diversity and inclusion efforts is an organizational priority and strategic oversight of our efforts is provided by our Compensation Committee. We have introduced diversity awareness programs focused on increasing the number of underrepresented persons in engineering roles in our refineries and corporate office. Our university recruiting team has partnered with historically Black colleges and universities to offer full-time and summer internship opportunities and various diversity and inclusion organizations at universities to sponsor and participate in events, such as the North Texas Women’s Energy Network and the National Society of Black Engineers Convention. In addition, to help foster a culture of inclusion, we have two employee resource groups focused on strengthening our support of women and veterans in the workplace.

Health & Safety
The safety of our employees, contractors and communities is an overarching priority and fundamental to our operational success. We are grounded by our “Goal Zero” vision, which reflects our belief that safe production can be achieved each and every day. Our commitment to safety is embedded throughout our organization, from frontline employees and contractors to our executive leadership and board of directors. Our Operational Excellence Management System provides the framework through which we identify, monitor and reduce risks. Our Environment, Health and Safety (“EHS”) Leadership Council, comprised of company executives, including our CEO, business unit leaders and corporate safety specialists, sets EHS strategy and reviews performance. The Environmental, Health, Safety and Public Policy Committee of our Board of Directors provides board-level oversight of our strategies and performance in these areas.

To achieve Goal Zero, our employee and contractor safety education and training programs are conducted on an ongoing basis. We set specific goals for workplace safety and measure attainment of those goals. Over the past five years ended December 31, 2020, our OSHA total recordable incident rate (“TRIR”) declined by 35 percent. In response to the coronavirus (“COVID-19”) pandemic, and with the health and safety of our employees as a top priority, we have temporarily modified our business practices by limiting employee and contractor presence at our facilities to essential operating personnel, using a work from home policy, restricting travel, and quarantining employees when necessary.
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Total Rewards & Development
We believe that the health of our company is linked to the performance and health of our people. We want to inspire and empower our employees to feel confident in their long-term well-being and are committed to offering a comprehensive and competitive total rewards programs for our employees, as benchmarked against our peers. While our benefit offerings vary depending on each country’s market practices, they are designed to support employee health, financial and emotional needs. Our benefits include comprehensive coverage for health care, a competitive retirement savings benefit, vacation and holiday time and other income protection and work life benefits. We also provide tools to help recognize and reward employee performance consistent with our One HFC Culture.

Consistent with our culture of ownership and growth, we offer training, development and engagement programs across every level of our organization to provide employees the opportunity to develop their career by enhancing skills and capabilities consistent with the needs of the business. In 2019, we launched HFC LEAD. “LEAD” stands for Leadership, Excellence and Development and is comprised of a number of programs focused on developing current and future leaders, including the Future HFC Leader Development, Front Line Leader, and Leading the HFC Way programs. We invested $6.0 million in our employee training and development programs in fiscal 2020.

Governmental Regulation
We are subject to numerous international, federal, state, provincial and local laws and regulations regulating worker health and safety, the discharge of substances into the environment, or otherwise relating to the protection of the environment and natural resources. Permits or other authorizations are required under these laws and regulations for the operation of our refineries, pipelines and related facilities, which can result in the imposition of costly reporting, installation of pollution control equipment and maintenance obligations. Moreover, these permits and authorizations are subject to revocation, modification and renewal, as well as challenges from third parties.

Failure to comply with these laws and regulations may result in the assessment of sanctions, including administrative, civil and criminal penalties; the imposition of investigatory, remedial or corrective action obligations or the incurrence of capital expenditures; the occurrence of delays in the permitting, development or expansion of projects; the issuance of injunctive relief limiting or prohibiting certain operations; and reputational harm. In addition, many environmental laws provide a mechanism for citizens to file suit against regulated facilities for alleged environmental violations. Compliance with applicable environmental laws, regulations and permits or other authorizations will continue to have an impact on our operations, the results of our operations and our capital expenditures.

Rate Regulation - Some of HEP’s existing pipelines are considered interstate common carrier pipelines subject to regulation by the Federal Energy Regulatory Commission (“FERC”) under the Interstate Commerce Act (the “ICA”). The ICA requires that tariff rates for oil pipelines, a category that includes crude oil and petroleum product pipelines, be just and reasonable and not unduly discriminatory. The ICA permits interested persons to challenge newly proposed or changed rates and authorizes FERC to suspend the effectiveness of such rates for a period of up to seven months and to investigate such rates. If, upon completion of an investigation, FERC finds that the new or changed rate is unlawful, it is authorized to require the carrier to refund the revenues in excess of the prior tariff collected during the pendency of the investigation. FERC also may investigate, upon complaint or on its own motion, rates that are already in effect and may order a carrier to change its rates prospectively. Upon an appropriate showing, a shipper may obtain reparations for damages sustained during the two years prior to the filing of a complaint.

The Energy Policy Act of 1992 deemed petroleum products pipeline tariff rates that were (i) in effect for the 365-day period ending on the date of enactment or (ii) in effect on the 365th day preceding enactment and had not been subject to complaint, protest or investigation during the 365-day period, in each case, to be just and reasonable or “grandfathered” under the ICA. The Energy Policy Act also limited the circumstances under which a complaint can be made against such grandfathered rates. Petroleum products pipelines may change their rates within prescribed ceiling levels that are tied to an inflation index. Shippers may protest rate increases made within the ceiling levels, but such protests must show that the portion of the rate increase resulting from application of the index is substantially in excess of the pipeline’s increase in costs from the previous year. A pipeline must, as a general rule, utilize the indexing methodology to change its rates. Cost-of-service ratemaking, market-based rates and settlement rates are alternatives to the indexing approach and may be used in certain specified circumstances to change rates.

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Clean Air Act - Our operations are subject to certain requirements of the Federal Clean Air Act (“CAA”) as well as related state and local laws and regulations. Certain CAA regulatory programs applicable to our facilities require capital expenditures for the installation of certain air pollution control devices, operational procedures to minimize emissions, and monitoring and reporting of emissions. Additionally, the Environmental Protection Agency (“EPA”) has the authority under the CAA to modify the formulation of the refined transportation fuel products we manufacture in order to limit the emissions associated with their final use. Also, the EPA has reduced several National Ambient Air Quality Standards (“NAAQS”), and implementation of such revised NAAQS could result in stricter permitting requirements, delay or the inability to obtain such permits, and increased expenditures for pollution control equipment, the costs of which could be significant. Moreover, in February 2016, a new EPA rule became effective that requires, among other things, benzene monitoring at the refinery fence line beginning in January 2018 and submittal of fence line monitoring data to the EPA on a quarterly basis; upgraded storage tank controls requirements, including new applicability thresholds; enhanced performance requirements for flares, continuous monitoring of flares and pressure release devices, and analysis and remedy of flare release events; compliance with emissions standards for delayed coking units; and requirements related to air emissions resulting from startup, shutdown and maintenance events. These new rules, as well as subsequent rulemaking under the CAA or similar laws, or new agency interpretations of existing laws and regulations, may necessitate additional expenditures in future years and result in increased costs on our operations.

Fuel Quality Regulation - We are subject to the EPA’s Control of Hazardous Air Pollutants from Mobile Sources (also known as the Mobile Source Air Toxics rule, or “MSAT2”) regulations that impose reductions in the benzene content of our produced gasoline. In addition to reducing benzene concentration in our gasoline, our refineries currently purchase benzene credits to meet these requirements. If economically justified or otherwise determined to be beneficial, we may implement additional benzene reduction projects to eliminate or reduce the need to purchase benzene credits.

Pursuant to the Energy Independence and Security Act of 2007 (“EISA”), and the EPA’s corresponding Renewable Fuel Standard (“RFS”) regulations, most refiners are required to blend increasing amounts of biofuels with refined products through 2022 or purchase Renewable Identification Numbers (“RINs”) in lieu of blending. Under the RFS, the percentage of renewable fuels that refineries are obligated to blend into their finished petroleum products is adjusted annually. In November 2018, the EPA finalized the RFS targets for 2019, which maintained the volume required for conventional (i.e., corn ethanol) renewable fuel, increased the volume required for advanced biofuels, and increased the volume required for cellulosic biofuel compared to the 2018 RFS requirements. The EPA also increased the biomass-based diesel volume for 2020 compared to 2019. The EPA has not yet finalized the 2021 RFS requirements for any fuel other than biodiesel, creating some uncertainty regarding our compliance obligations for 2021. Because the EISA requires specified volumes of biofuels, if the demand for motor fuels decreases in future years, even higher percentages of biofuels may be required.

The EPA has historically used its waiver authority to establish volumes lower than the statutory volumes required by EISA, but the EPA’s interpretation of its waiver authority, as well as its implementation of the RFS, has been subject to numerous court challenges. Lawsuits have been filed by the renewable fuel industry challenging the EPA's grant of small refinery exemptions. For additional information regarding risks relating to our small refinery exemptions, see Item 1A, “Risk Factors - The availability and cost of renewable identification numbers and other required credits could have an adverse effect on our financial condition and results of operations.” Legal challenges of the EPA's decision are ongoing. We cannot predict the outcome of these matters or whether they may result in increased RFS compliance costs. There also continues to be a shortage of advanced biofuel production resulting in increased difficulties meeting RFS mandates. As a result, we may be unable to blend sufficient quantities of renewable fuel to meet our requirements and, therefore, may have to purchase an increasing number of RINs. It is not possible at this time to predict with certainty what those volumes or costs may be, but given the potential increase in volumes and the volatile price of RINs, increases in renewable volume requirements could have an adverse impact on our results of operations.

Finally, while there is no current regulatory standard that authenticates RINs that may be purchased on the open market from third parties, we believe that the RINs we purchase are from reputable sources, are valid and serve to demonstrate compliance with applicable RFS requirements. However, if any of the RINs purchased by us on the open market are subsequently found by the EPA to be invalid, we could incur significant costs, penalties, or other liabilities in connection with replacing any invalid RINs and resolving any enforcement action brought by the EPA.

In April 2014, the EPA promulgated the Tier 3 Motor Vehicle Emission and Fuel Standards, which requires a reduction in annual average gasoline sulfur content from 30 ppm to 10 ppm. These requirements, other CAA requirements, and other presently existing or future environmental regulations may cause us to make substantial capital expenditures and purchase sulfur credits at significant cost to enable our refineries to produce products that meet applicable requirements.

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Climate Change - In recent years, various legislative and regulatory measures to address climate change and greenhouse gas (“GHG”) emissions (including carbon dioxide, methane and nitrous oxides) have been discussed or implemented. They include proposed and enacted federal regulation and state actions to develop statewide, regional or nationwide programs designed to control and reduce GHG emissions from fixed sources, such as our refineries, as well as power plants, mobile transportation sources and fuels. Measures to date have included but are not limited to cap and trade programs, carbon taxes, vehicle efficiency standards, electric vehicle mandates, combustion engine phaseouts and low carbon fuel standards. Although it is not possible to predict the requirements of any GHG legislation that may be enacted, any laws or regulations that may be adopted to restrict or reduce GHG emissions will likely require us to incur increased operating and capital costs. In August 2015, the EPA finalized the “Clean Power Plan” requiring states to reduce carbon dioxide emissions from coal-fired power plants that will likely result in a combination of plant closures, switching to renewable energy and natural gas, and demand reduction. However, in July 2019, the EPA issued a replacement rule titled the Affordable Clean Energy (“ACE”) Rule, which replaced the Clean Power Plan and is focused solely on electric generating units. However, in January 2021, the D.C. Circuit vacated the ACE rule, and the Biden Administration may consider reimplementing the Clean Power Plan or a similar rule. Neither the Clean Power Plan nor the Affordable Clean Energy Rule would directly affect our operations. To the extent the EPA fully implements a rule that imposes higher costs on electricity generating units it could result in increased power costs for our refineries in future years.

EPA rules require us to report GHG emissions from our refinery operations and consumer use of fuel products produced at our refineries on an annual basis. While the cost of compliance with the reporting rule is not material, data gathered under the rule may be used in the future to support additional regulation of GHG. Moreover, the EPA directly regulates GHG emissions from refineries and other major sources through the Prevention of Significant Deterioration (“PSD”) and Federal Operating Permit programs and may require Best Available Control Technology (“BACT”) for GHG emissions above a certain threshold if emissions of other pollutants would otherwise require PSD permitting. While this does not impose any limits or controls on GHG emissions from current operations, future projects or operational changes that increase GHG emissions, such as capacity increases, may be subject to emission limits or technological requirements pertaining to GHG emissions, such as BACT.

Severe limitations on GHG emissions could also adversely affect demand for the gasoline that we produce. Recently, activists concerned about the potential effects of climate change have directed their attention at sources of funding for fossil-fuel energy companies, which has resulted in certain financial institutions, funds and other sources of capital restricting or eliminating their investment in oil and natural gas activities. There is also a risk that financial institutions will be required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. Recently, the Federal Reserve announced that it has joined the Network for Greening the Financial System, a consortium of financial regulators focused on addressing climate-related risks in the financial sector. Ultimately, this could make it more difficult to secure funding for exploration and production activities and result in decreased production of oil, which indirectly could have an adverse impact on our operations. Finally, it should be noted that some scientists have concluded that increasing concentrations of GHGs in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, floods and other extreme weather events; if any such effects were to occur, they could have an adverse effect on our operations.

The incoming administration is proposing an “all of government” approach to climate change in which the federal government would use not only its regulatory and enforcement authority but also its policy and purchasing power to encourage investment and use of renewable energy sources and to otherwise impede and reduce fossil fuel use. This approach may include elements that could directly or indirectly result in decreased demand for transportation fuel and could have an adverse impact on our operations. For example, on January 27, 2021, President Biden issued an executive order that commits to substantial action on climate change, calling for, among other things, the increased use of zero-emissions vehicles by the federal government, the elimination of subsidies provided to the fossil fuel industry, and increased emphasis on climate-related risks across governmental agencies and economic sectors.

Water Discharges - Our operations are also subject to the Federal Clean Water Act (“CWA”), the Federal Safe Drinking Water Act (“SDWA”) and comparable state and local requirements. The CWA, the SDWA and analogous laws prohibit any discharge into surface waters, ground waters, injection wells and publicly-owned treatment works except in conformance with legal authorization, such as pre-treatment permits and National Pollutant Discharge Elimination System (“NPDES”) permits, issued by federal, state and local governmental agencies. The EPA commenced a study from 2015-2017 related to the discharges of metals and dioxin from petroleum refining operations and wastewater discharges from refineries in connection with the consideration of new effluent limitation guidelines that would be incorporated into refinery sector NPDES permits. To date, the EPA has not proposed any new effluent limitation guidelines applicable to our operations, but future rulemakings related to this issue could require us to incur increased costs related to the treatment of wastewater resulting from our operations.

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The CWA also regulates filling or discharges to wetlands and other “waters of the United States.” On January 23, 2020, the EPA, in conjunction with the U.S. Army Corps of Engineers (the “Corps”), issued a final rule regarding the definition of “waters of the United States,” which narrowed the regulatory reach of the CWA regulations relative to a prior 2015 rulemaking. The final rule became effective June 22, 2020. Because the rule does not expand the scope of the CWA’s jurisdiction, it will not likely adversely impact our operations; however, the final rule is subject to litigation, and multiple challenges to the EPA's prior rulemakings remains pending, both of which create uncertainty. Additionally, the new administration may seek to revise or withdraw the final rule, creating further uncertainty.

Hazardous Substances and Wastes - We generate wastes that may be subject to the Resource Conservation and Recovery Act and comparable state and local requirements. The EPA and various state agencies have limited the approved methods of disposal for certain hazardous and non-hazardous wastes. Although the EPA is currently working on several rulemakings that could impact how our refineries manage various waste streams, it does not appear that these rules will significantly impact our refineries.

The Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”), also known as “Superfund,” imposes strict, and under certain circumstances, joint and several liability on certain classes of persons who are considered to be responsible for the cost of cleaning up hazardous substances that have been released into the environment and for damages to natural resources. These persons include current and former owners or operators of property where a release has occurred, and any persons who disposed of, or arranged for the transport or disposal of, hazardous substances at the property. In the course of our historical operations, as well as in our current operations, we have generated waste, some of which falls within the statutory definition of a “hazardous substance” and some of which may have been disposed of at sites that may be subject to cleanup and cost recovery actions under CERCLA in the future. Similarly, locations now owned or operated by us, where third parties have disposed such hazardous substances in the past, may also be subject to cleanup and cost recovery actions under CERCLA. Some states have enacted laws similar to CERCLA which impose similar responsibilities and liabilities on responsible parties. It is also not uncommon for neighboring landowners and other third parties to file claims under state law for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment.

Oil Pollution Act - The Oil Pollution Act of 1990 (“OPA”) and regulations thereunder generally subject owners and operators of facilities to strict, joint and several liability for all containment and cleanup costs, natural resource damages, and potential governmental oversight costs arising from oil spills into the waters of the U.S. The OPA also imposes ongoing requirements on a responsible party, including the preparation of oil spill response plans and proof of financial responsibility to cover environmental cleanup and restoration costs that could be incurred in connection with an oil spill.

Other Environmental Regulations - Our Canadian assets and operations are also required to comply with various Canadian federal, provincial and municipal regulations. The regulations are in many cases conceptually similar to those described above for our U.S. operations. The principal legislation affecting our Canadian operations is the Canadian Environmental Protection Act, the Fisheries Act, the Greenhouse Gas Pollution Pricing Act and their regulations at a federal level and various provincial statutes and regulations such as the Ontario Environmental Protection Act, the Ontario Occupational Health and Safety Act and the Ontario Water Resources Act. All these laws contain broad prohibitions against causing harm to air, land, water, people or any other living organism and in many cases contain detailed prescriptive rules governing many aspects of our operations. Regulatory trends towards more stringent emission requirements and operating controls are expected to continue at federal, provincial and local levels.

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Additionally, our assets and operations in the Netherlands are required to comply with Dutch regulations that are similar to, and in some cases more stringent than, those described above for our U.S. operations. The statutes to which our Dutch assets and operations are subject include the Environmental Protection Act, the Activities Decree, the Environmental Licensing (General Provisions) Act, the Water Act, the Soil Protection Act, the Major Accidents (Risks) Decree, the European Birds and Habitats Directive, the Economic Offences Act and other subordinate decrees and regulations relative to environmental control, permitting and enforcement. However, a large legislative operation is being developed that should lead to the integration of all environmental laws in one, being the Environment and Planning Act, which is expected to enter into force in January 2022. Generally, these regulations create a system of environmental permits covering the most significant emissions to water, air and soil, as well as other environmental impacts. The Netherlands also participates in certain broader European legal initiatives, including GHG cap and trade programs. Additionally, in December 2019, the High Council of the Netherlands upheld a court order for the government of the Netherlands to reduce the country's GHG emissions by 25% (compared to 1990) by 2020, and in January 2020,the Climate Act came into force, with the goal of significantly reducing GHG emissions by 49% (compared to 1990) by 2030 and by at least 95% (compared to 1990) by 2050. Furthermore, the target is that 100% of the electricity production will be CO2 neutral in 2050. The Climate Act also establishes that the government must prepare a Climate Plan. The first Climate Plan covers the period between 2021 and 2030 and includes measures in view of a reduction of 49% of GHG emissions in 2030. It is unclear what further measures the Dutch government will take to reduce GHG emissions pursuant to this law.

Enforcement and Litigation Proceedings - As is the case with all companies engaged in industries similar to ours, we face potential exposure to future claims and lawsuits involving environmental matters. These matters include soil and water contamination, air pollution, GHG emissions, personal injury and property damage allegedly caused by substances that we manufactured, handled, used, released or disposed. We currently have environmental remediation projects that relate to recovery, treatment and monitoring activities resulting from past releases of refined product and crude oil into the environment. As of December 31, 2020, we had an accrual of $115.0 million related to such environmental liabilities.

We are and have been the subject of various local, state, provincial, federal and private proceedings and inquiries relating to compliance with environmental laws and regulations and conditions, including those discussed above. Compliance with current and future environmental regulations is expected to require additional expenditures, including expenditures for investigation and remediation, which may be significant. To the extent that future expenditures for these purposes are material and can be reasonably determined, these costs are disclosed and accrued, if applicable.

Occupational Health and Safety - Our operations are subject to various laws and regulations relating to occupational health and safety, including the Occupational Safety and Health Act (“OSHA”), comparable state statutes, Canadian regulations applicable to our operations in Canada and Dutch regulations, including the Health and Safety Act, applicable to our operations in the Netherlands. We maintain a comprehensive safety program, including mechanical integrity and safety-related maintenance programs and training, to ensure compliance with all applicable laws and regulations to protect the safety of our workers and the public. Some of our operations are also subject to OSHA Process Safety Management (“PSM”) regulations and EPA Risk Management Plan (“RMP”) regulations, both of which are designed to prevent or minimize chemical accidents and any resulting releases of toxic, reactive, flammable or explosive chemicals. In January 2017, the EPA revised the RMP requirements for incident investigation and accident history reporting, emergency preparedness, and the performance of process hazard analyses and third party compliance audits. Many of the revised requirements do not become effective until 2021, and the EPA issued a final rule in December 2019 that rescinded several of the requirements of the 2017 rule. The new administration may consider reissuing some of the rescinded requirements or making other changes. Also in January 2017, OSHA announced changes to its National Emphasis Program, which specifically identified oil refineries as facilities for increased inspections and instructed inspectors to use data gathered from EPA RMP inspections to identify refiners for additional PSM inspections. Compliance with applicable state and federal occupational health and safety laws and regulations, as well as environmental regulations, has required, and continues to require, substantial expenditures.

Occupational health and environmental legislation, regulations and regulatory programs change frequently. We cannot predict what additional occupational health and environmental legislation or regulations will be enacted or become effective in the future or how existing or future laws or regulations will be administered or interpreted with respect to our operations. Compliance with more stringent laws or regulations or adverse changes in the interpretation of existing laws or regulations by government agencies could have an adverse effect on our financial position and the results of our operations and could require substantial expenditures for the installation and operation of systems and equipment that we do not currently possess.

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Insurance
Our operations are subject to hazards of 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.

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.



Item 1A.Risk Factors
Risk Factor Summary

Investing in us involves a degree of risk. You should carefully consider all information in this Form 10-K, including the Management’s Discussion & Analysis section and the financial statements and related notes, prior to investing in our common stock. These risks and uncertainties include, but are not limited to, the following:

Risks Related to our Business:

The prices of crude oil and refined and finished lubricant products materially affect our profitability, and are dependent upon many factors that are beyond our control.
To successfully operate our facilities, we are required to expend significant amounts for capital outlays and operating expenditures. If we are unable to complete capital projects at their expected costs or in a timely manner, or if the market conditions assumed in our project economics deteriorate, our financial condition, results of operations, or cash flows could be materially and adversely affected.
The COVID-19 pandemic or any other widespread outbreak of an illness or pandemic or other public health crisis, and actions taken in response thereto, as well as certain developments in the global oil markets, have had and may continue to have a material adverse effect on our operations, business, financial condition and results of operations and cash flows.
Competition in the refining and marketing industry and in our lubricants and specialty products segment is highly competitive, an increase in competition could adversely affect our earnings and profitability.
A disruption to or proration of the refined product distribution systems or manufacturing facilities we utilize could negatively impact our profitability.
A material decrease in the supply of crude oil or other raw materials available to our refineries and other facilities could significantly reduce our production levels and negatively affect our operations.
We depend upon HEP for a substantial portion of the crude supply and distribution network that serve our refineries, and we own a significant equity interest in HEP.
Our acquisition strategy involves numerous risks, any of which could adversely affect us.
An impairment of our long-lived assets or goodwill could reduce our earnings or negatively impact our financial condition and results of operations.
Potential product, service or other related liability claims and litigation could adversely affect our business, reputation and results of operations.
We sell many of our lubricants and specialty products through distributors, which presents risks that could adversely affect our operating results.
Our hedging transactions may limit our gains and expose us to other risks.

Risks Related to Government Regulation

There are various risks associated with greenhouse gases and climate change, including increased regulation of CO2 emissions, that could result in increased operating costs and litigation and reduced demand for the refined products we produce and investment in our industry.
The availability and cost of renewable identification numbers and other required credits could have an adverse effect on our financial condition and results of operations.
We are subject to significant regulation and oversight by governmental agencies. We incur significant costs, and expect to incur additional costs in the future, to comply with existing, new and changing environmental, energy, health and safety laws and regulations, and face potential exposure for environmental matters.
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Our business is subject to complex and evolving global laws, regulations and security standards regarding privacy, cybersecurity and data protection, which could result in claims, increased cost of operations, or otherwise harm our business.

General Risk Factors

Cyberattacks, data security breaches, information technology system failures, network disruptions, terrorist attacks or domestic vandalism, continued global hostilities or other sustained military campaigns could have a material adverse effect on our business, financial condition and results of operations.
Our operations are subject to catastrophic losses, operational hazards and unforeseen interruptions and other disruptive risks for which we may not be adequately insured.
We may not be able to obtain funding on acceptable terms or at all because of volatility and uncertainty in the credit and capital markets.. Our credit facility contains certain covenants and restrictions that may constrain our business and financing activities.
Our business is subject to the risks of international operations, including currency fluctuations.
We are exposed to the credit risks, and certain other risks, of our key customers and vendors.
We may be unable to pay future dividends.
We may be unable to adequately protect our intellectual property, which may increase our cost of doing business or otherwise hurt our ability to compete in the market.
Changes in our credit profile may affect our relationship with our suppliers, which could have a material adverse effect on our liquidity and limit our ability to purchase sufficient quantities of crude oil to operate our refineries at desired capacity.
Our business may suffer due to a departure of any of our key employees, a shortage of skilled labor or disruptions in our workforce. A portion of our workforce is unionized, and any disruptions in our labor force or adverse employee relations could adversely affect our business.
The market price of our common stock may fluctuate significantly, and the value of a stockholder’s investment could be impacted.
Compliance with and changes in tax laws could materially and adversely impact our financial condition, results of operations and cash flows.

Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial may also materially and adversely affect our business operations. If any of the following risks were to actually occur, our business, financial condition, results of operations could be materially and adversely affected. The headings provided in this Item 1A. are for convenience and reference purposes only and shall not affect or limit the extent or interpretation of the risk factors.

RISKS RELATED TO OUR BUSINESS

The prices of crude oil and refined and finished lubricant products materially affect our profitability, and are dependent upon many factors that are beyond our control, including general market demand and economic conditions, seasonal and weather-related factors, regional and grade differentials and governmental regulations and policies.

Among these factors is the demand for crude oil and refined and finished lubricant products, which is largely driven by the conditions of local and worldwide economies, as well as by weather patterns, changes in consumer preferences and the taxation of these products relative to other energy sources. Governmental regulations and policies, particularly in the areas of taxation, energy and the environment, and more recently in response to the COVID-19 pandemic, also have a significant impact on our activities. Operating results can be affected by these industry factors, product and crude pipeline capacities, crude oil differentials (including regional and grade differentials), changes in transportation costs, accidents or interruptions in transportation, competition in the particular geographic areas that we serve, global market conditions, actions by foreign nations and factors that are specific to us, such as the success of particular marketing programs and the efficiency of our refinery operations. The demand for crude oil and refined and finished lubricant products can also be reduced due to a local or national recession or other adverse economic condition, which results in lower spending by businesses and consumers on gasoline and diesel fuel, higher gasoline prices due to higher crude oil prices, a shift by consumers to more fuel-efficient vehicles or alternative fuel vehicles (such as ethanol or wider adoption of gas/electric hybrid vehicles), or an increase in vehicle fuel economy, whether as a result of technological advances by manufacturers, legislation mandating or encouraging higher fuel economy or the use of alternative fuel.

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We do not produce crude oil and must purchase all our crude oil, the price of which fluctuates based upon worldwide and local market conditions. Our profitability depends largely on the spread between market prices for refined petroleum products and crude oil prices. This margin is continually changing and may fluctuate significantly from time to time. Crude oil and refined products are commodities whose price levels are determined by market forces beyond our control. For example, the reversal of certain existing pipelines or the construction of certain new pipelines transporting additional crude oil or refined products to markets that serve competing refineries could affect the market dynamic that has allowed us to take advantage of favorable pricing. A deterioration of crack spreads or price differentials between domestic and foreign crude oils could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Additionally, due to the seasonality of refined products markets and refinery maintenance schedules, results of operations for any particular quarter of a fiscal year are not necessarily indicative of results for the full year and can vary year to year in the event of unseasonably cool weather in the summer months and/or unseasonably warm weather in the winter months in the markets in which we sell our petroleum products. In general, prices for refined products are influenced by the price of crude oil. Although an increase or decrease in the price for crude oil may result in a similar increase or decrease in prices for refined products, there may be a time lag in the realization of the similar increase or decrease in prices for refined products. The effect of changes in crude oil prices on operating results, therefore, depends in part on how quickly refined product prices adjust to reflect these changes. A substantial or prolonged increase in crude oil prices without a corresponding increase in refined product prices, a substantial or prolonged decrease in refined product prices without a corresponding decrease in crude oil prices, or a substantial or prolonged decrease in demand for refined products could have a significant negative effect on our earnings and cash flow. Also, our crude oil and refined products inventories are valued at the lower of cost or market under the last-in, first-out (“LIFO”) inventory valuation methodology. If the market value of our inventory were to decline to an amount less than our LIFO cost, we would record a write-down of inventory and a non-cash charge to cost of products sold even when there is no underlying economic impact at that point in time. Continued volatility in crude oil and refined products prices could result in lower of cost or market inventory charges in the future, or in reversals reducing cost of products sold in subsequent periods should prices recover. For example, we recorded a charge and increase to cost of products sold in the amount of $78.5 million and a non-cash decrease to cost of products sold in the amount of $119.8 million for the years ended December 31, 2020 and 2019, respectively.

To successfully operate our facilities, we are required to expend significant amounts for capital outlays and operating expenditures. If we are unable to complete capital projects at their expected costs or in a timely manner, or if the market conditions assumed in our project economics deteriorate, our financial condition, results of operations, or cash flows could be materially and adversely affected.

Our facilities consist of many processing units, a number of which have been in operation for many years. One or more of the units may require unscheduled downtime for unanticipated maintenance or repairs that are more frequent than our scheduled turnaround for such units. Scheduled and unscheduled maintenance could reduce our revenues during the period of time that the units are not operating. We have taken significant measures to expand and upgrade units in our facilities by installing new equipment and redesigning older equipment to improve refinery capacity or to address changes in consumer preferences, such as the growing demand for renewable diesel and other lower carbon fuels. The installation and redesign of key equipment at our facilities, including the conversion of our Cheyenne Refinery to renewable diesel production and the construction of the renewable diesel and pre-treatment units at our Artesia facility, involves significant uncertainties, including the following: our upgraded equipment may not perform at expected levels; operating costs of the upgraded equipment may be higher than expected; the yield and product quality of new equipment may differ from design and/or specifications and redesign, modification or replacement of the equipment may be required to correct equipment that does not perform as expected, which could require facility shutdowns until the equipment has been redesigned or modified. Any of these risks associated with new equipment, redesigned older equipment, or repaired equipment could lead to lower revenues or higher costs or otherwise have a negative impact on our future financial condition and results of operations. In the third quarter of 2020, we permanently ceased refining operations at our Cheyenne Refinery and subsequently began converting certain assets at the Cheyenne Refinery to renewable diesel production due, in part, to uncompetitive operating and maintenance costs for the refinery.

One of the ways we may grow our business is through the construction of new refinery processing units (or the purchase and refurbishment of used units from another refinery) and the conversion or expansion of existing ones, such as the conversion of the Cheyenne Refinery to renewable diesel production and the connection of a new renewable diesel and a pre-treatment unit at the Navajo Refinery. Projects are generally initiated to increase the yields of higher-value products, increase the amount of lower cost crude oils that can be processed, increase refinery production capacity, meet new governmental requirements or take advantage of new government incentive programs, or maintain the operations of our existing assets. Additionally, our growth strategy includes projects that permit access to new and/or more profitable markets, including the growing demand for renewable diesel and other lower carbon fuels. The construction process involves numerous regulatory, environmental, political, and legal uncertainties, most of which are not fully within our control, including:
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third party challenges to, denials, or delays with respect to the issuance of requisite regulatory approvals and/or obtaining or renewing permits, licenses, registrations and other authorizations;
societal and political pressures and other forms of opposition;
compliance with or liability under environmental regulations;
unplanned increases in the cost of construction materials or labor;
disruptions in transportation of modular components and/or construction materials;
severe adverse weather conditions, natural disasters, terrorists or cyberattacks, domestic vandalism or other events (such as equipment malfunctions, explosions, fires, spills) affecting our facilities, or those of vendors and suppliers;
shortages of sufficiently skilled labor, or labor disagreements resulting in unplanned work stoppages;
market-related increases in a project's debt or equity financing costs; and/or
nonperformance or force majeure by, or disputes with, vendors, suppliers, contractors, or sub-contractors involved with a project.

If we are unable to complete capital projects at their expected costs or in a timely manner our financial condition, results of operations, or cash flows could be materially and adversely affected. Delays in making required changes or upgrades to our facilities could subject us to fines or penalties as well as affect our ability to supply certain products we make. In addition, our revenues may not increase immediately upon the expenditure of funds on a particular project. For instance, the construction of our previously announced renewable diesel units and pre-treatment unit at our Cheyenne and Artesia facilities will occur over an extended period of time and we will not receive any material increases in revenues until after completion of the project. Moreover, we may construct facilities to capture anticipated future growth in demand for refined products or renewable diesel in a region in which such growth does not materialize. As a result, new capital investments may not achieve our expected investment return, which could adversely affect our financial condition or results of operations.

In addition, we expect to execute turnarounds at our refineries, which involve numerous risks and uncertainties. These risks include delays and incurrence of additional and unforeseen costs. The turnarounds allow us to perform maintenance, upgrades, overhaul and repair of process equipment and materials, during which time all or a portion of the refinery will be under scheduled downtime.

Our forecasted internal rates of return are also based upon our projections of future market fundamentals which are not within our control, including changes in general economic conditions, available alternative supply, global market conditions, actions by foreign nations and customer demand.

The COVID-19 pandemic or any other widespread outbreak of an illness or pandemic or other public health crisis, and actions taken in response thereto, as well as certain developments in the global oil markets, have had and may continue to have a material adverse effect on our operations, business, financial condition and results of operations and cash flows.

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, significantly reduced global demand for oil, gas and refined products, and created significant volatility and disruption of financial and commodity markets in the first half of 2020. 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 demand for refined products stabilized in the second half of 2020, this combination of events contributed to an overall drop in prices, as well as a lack of forward visibility in demand, for crude oil and refined products in 2020. See “Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations - Impact of COVID-19 on Our Business” for additional discussion of the impact of COVID-19 on our business.

In addition, the supply and demand for refined and finished lubricant products depends 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;
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the availability, distribution and effectiveness of vaccines for COVID-19;
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;
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, deterioration in gross margins and the economic slowdown resulting from the COVID-19 pandemic was a contributing factor in certain goodwill and long-lived asset impairments we recorded in 2020. See “An impairment of our goodwill or long-lived assets could reduce our earnings or negatively impact our financial condition and results of operations” for further discussion of the impairment risk in our business and the impairments we recorded in 2020. 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.

The effects of COVID-19 are difficult to predict and the duration of any potential business disruption or the extent to which it may negatively affect our operating results is uncertain. Any additional 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 continue to monitor the situation to assess further possible implications to our business and to take actions in an effort to mitigate adverse consequences. The effects of the COVID-19 pandemic, as well as the volatility in global oil markets, while uncertain, have and may continue to, materially adversely affect our business, financial condition, results of operations and/or cash flows, as well as our ability to pay dividends to our shareholders.

Competition in the refining and marketing industry is intense, and an increase in competition in the markets in which we sell our products could adversely affect our earnings and profitability.

We compete with a broad range of refining and marketing companies, including certain multinational oil companies. Because of their geographic diversity, larger and more complex refineries, integrated operations and greater resources, some of our competitors may be better able to withstand volatile market conditions, to obtain crude oil in times of shortage and to bear the economic risks inherent in all areas of the refining industry.

We are not engaged in petroleum exploration and production activities and do not produce any of the crude oil feedstocks used at our refineries. We do not have a retail business and therefore are dependent upon others for outlets for our refined products. Certain of our competitors, however, obtain a portion of their feedstocks from company-owned production and have retail outlets. Competitors that have their own production or extensive retail outlets, with brand-name recognition, are at times able to offset losses from refining operations with profits from producing or retailing operations, and may be better positioned to withstand periods of depressed refining margins or feedstock shortages.

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In recent years there have been several refining and marketing consolidations or acquisitions between entities competing in our geographic market. These transactions could increase the future competitive pressures on us.

The markets in which we compete may be impacted by competitors' plans for expansion projects and refinery improvements that could increase the production of refined products in our areas of operation and significantly affect our profitability.

Also, the potential operation of new or expanded refined product transportation pipelines, or the conversion of existing pipelines into refined product transportation pipelines, could impact the supply of refined products to our existing markets and negatively affect our profitability.

In addition, we compete with other industries that provide alternative means to satisfy the energy and fuel requirements of our industrial, commercial and individual consumers. The more successful these alternatives become as a result of governmental regulations, technological advances, consumer demand, improved pricing or otherwise, the greater the impact on pricing and demand for our products and our profitability. There are presently significant governmental and consumer pressures to increase the use of alternative fuels in the United States.

The market for our lubricants and specialty products segment is highly competitive and requires us to continuously develop and introduce new products and product enhancements.

Our ability to grow our Lubricants and Specialty Products segment depends, in part, on our ability to continuously develop, manufacture and introduce new products and product enhancements on a timely and cost-effective basis, in response to customers’ demands for higher performance process lubricants, coatings, greases and other product offerings. Our competitors may develop new products or enhancements to their products that offer performance, features and lower prices that may render our products less competitive or obsolete, and, as a consequence, we may lose business and/or significant market share. Our efforts to respond to changes in consumer demand in a timely and cost-efficient manner to drive growth could be adversely affected by unfavorable margins or difficulties or delays in product development and service innovation, including the inability to identify viable new products, successfully complete research and development, obtain regulatory approvals, obtain intellectual property protection or gain market acceptance of new products or service techniques. The development and commercialization of new products require significant expenditures over an extended period of time, and some products that we seek to develop may never become profitable, and we could be required to write-off our investments related to a new product that does not reach commercial viability.

A disruption to or proration of the refined product distribution systems or manufacturing facilities we utilize could negatively impact our profitability.

We utilize various common carrier or other third party pipeline systems to deliver our products to market. The key systems utilized by the El Dorado, Navajo, Woods Cross, and Tulsa Refineries are NuStar Energy and Magellan, SFPP and Plains, Chevron and UNEV, and Magellan, respectively.

Our U.S. refineries also utilize systems owned by HEP. If these key pipelines or their associated tanks and terminals become inoperative or decrease the capacity available to us, we may not be able to sell our product, or we may be required to hold our product in inventory or supply products to our customers through an alternative pipeline or by rail or additional tanker trucks from the refinery, all of which could increase our costs and result in a decline in profitability.

We have manufacturing facilities in foreign countries that support the Lubricants and Specialty Products segment. If one of our facilities is damaged or disrupted, resulting in production being halted for an extended period, we may not be able to timely supply our customers. We take steps to mitigate this risk, including business continuity and contingency planning and procuring property insurance (including business interruption) and casualty insurance. Nevertheless, the loss of sales in any one region over an extended period of time could have a material adverse effect on our business, financial condition and results of operations.

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A material decrease in the supply of crude oil or other raw materials available to our refineries and other facilities could significantly reduce our production levels and negatively affect our operations.

To maintain or increase production levels at our refineries, we must continually contract for crude oil supplies from third parties. There are a limited number of crude oil suppliers in certain geographic regions, and in such cases, we may be required to source from a single third party supplier. If we are unable to maintain or extend our existing contracts with any such crude oil suppliers, or enter into new agreements on similar terms, the supply of crude oil could be adversely impacted, or we may incur a higher cost. A material decrease in crude oil production from the fields that supply our refineries, as a result of depressed commodity prices, lack of drilling activity, natural production declines, catastrophic events or otherwise, could result in a decline in the volume of crude oil available to our refineries. In addition, any prolonged disruption of a significant pipeline that is used in supplying crude oil to our refineries or the potential operation of a new, converted or expanded crude oil pipeline that transports crude oil to other markets could result in a decline in the volume of crude oil available to our refineries. Such an event could result in an overall decline in volumes of refined products processed at our refineries and therefore a corresponding reduction in our cash flow. In addition, the future growth of our operations will depend in part upon whether we can contract for additional supplies of crude oil at a greater rate than the rate of natural decline in our currently connected supplies. If we are unable to secure additional crude oil supplies of sufficient quality or crude pipeline expansion to our refineries, we will be unable to take full advantage of current and future expansion of our refineries' production capacities.

For certain raw materials and utilities used by our refineries and other facilities, there are a limited number of suppliers and, in some cases, we source from a single supplier and/or suppliers in economies that have experienced instability or the supplies are specific to the particular geographic region in which a facility is located. Any significant disruption in supply could affect our ability to obtain raw materials, or increase the cost of such raw materials, which could significantly reduce our production levels or have a material adverse effect on our business, financial condition and results of operations. In addition, certain raw materials that we use are subject to various regulatory laws, and a change in the ability to legally use such raw materials may impact our liquidity, financial position and results of operations.

It is also common in the refining industry for a facility to have a sole, dedicated source for its utilities, such as steam, electricity, water and gas. Having a sole or limited number of suppliers may limit our negotiating power, particularly in the case of rising raw material costs. Any new supply agreements we enter into may not have terms as favorable as those contained in our current supply agreements.

Additionally, there is growing concern over the reliability of water sources. The decreased availability or less favorable pricing for water as a result of population growth, drought or regulation could negatively impact our operations.

If our raw material, utility or water supplies were disrupted, our businesses may incur increased costs to procure alternative supplies or incur excessive downtime, which would have a direct negative impact on our operations.

We depend upon HEP for a substantial portion of the crude supply and distribution network that serve our refineries, and we own a significant equity interest in HEP.

At December 31, 2020, we owned a 57% limited partner interest and a non-economic general partner interest in HEP. HEP operates a system of crude oil and petroleum product pipelines, distribution terminals and refinery tankage in Idaho, Kansas, Nevada, New Mexico, Oklahoma, Texas, Utah, Washington and Wyoming and refinery units in Kansas and Utah. HEP generates revenues by charging tariffs for transporting petroleum products and crude oil through its pipelines, leasing certain pipeline capacity to third parties, charging fees for terminalling refined products and other hydrocarbons and storing and providing other services at its terminals. HEP serves the El Dorado, Navajo, Woods Cross and Tulsa Refineries under several long-term pipeline and terminal, tankage and throughput agreements expiring in 2022 through 2036 serves the El Dorado Refinery under long-term tolling agreements expiring in 2030 and serves the Woods Cross Refinery under long-term tolling agreements expiring in 2031. Furthermore, our financial statements include the consolidated results of HEP. HEP is subject to its own operating and regulatory risks, including, but not limited to:

its reliance on its significant customers, including us;
competition from other pipelines;
environmental regulations affecting pipeline operations;
operational hazards and risks;
pipeline tariff regulations affecting the rates HEP can charge;
limitations on additional borrowings and other restrictions due to HEP's debt covenants; and
other financial, operational and legal risks.

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The occurrence of any of these risks could directly or indirectly affect HEP's as well as our financial condition, results of operations and cash flows as HEP is a consolidated VIE. Additionally, these risks could affect HEP's ability to continue operations which could affect their ability to serve our supply and distribution network needs.

While we own a 57% limited partner interest and a non-economic general partner interest in HEP, HEP is a publicly-traded master limited partnership and is a legally distinct entity. Conflicts of interest may arise between us and HEP, which may subject us to claims from HEP's public unitholders.

For additional information about HEP, see “Holly Energy Partners, L.P.” under Items 1 and 2, “Business and Properties.” For risks related to HEP's business, see Item 1A of HEP's Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Our acquisition strategy involves numerous risks, any of which could adversely affect us.

An additional component of our growth strategy is to selectively acquire complementary assets or businesses for our refining operations in order to increase earnings and cash flow. Our ability to do so will be dependent upon a number of factors, including our ability to identify attractive acquisition candidates, consummate acquisitions on favorable terms, successfully integrate acquired assets and obtain financing to fund acquisitions and to support our growth, and other factors beyond our control. Risks associated with acquisitions include those relating to:

diversion of management time and attention from our existing business;
challenges in managing the increased scope, geographic diversity and complexity of operations and inefficiencies that may result therefrom;
difficulties in integrating the financial, technological and management standards, processes, procedures and controls of an acquired business with those of our existing operations;
liability for known or unknown environmental conditions or other contingent liabilities not covered by indemnification or insurance;
greater than anticipated expenditures required for compliance with environmental or other regulatory standards or for investments to improve operating results;
difficulties or delays in achieving anticipated operational improvements or benefits or inaccurate assumptions about future synergies or revenues;
incurrence of additional indebtedness to finance acquisitions or capital expenditures relating to acquired assets; and
issuance of additional equity, which could result in further dilution of the ownership interest of existing stockholders.

Any acquisitions that we do consummate may have adverse effects on our business and operating results.

An impairment of our goodwill or long-lived assets could reduce our earnings or negatively impact our financial condition and results of operations.

An impairment of our goodwill or long-lived assets could reduce our earnings or negatively impact our results of operations and financial condition. We continually monitor our business, the business environment and the performance of our operations to determine if an event has occurred that indicates that a goodwill or long-lived asset may be impaired. If a triggering event occurs, which is a determination that involves judgment, we may be required to utilize cash flow projections to assess our ability to recover the carrying value based on the ability to generate future cash flows. We may also conduct impairment testing based on both the guideline public company and guideline transaction methods. Our goodwill and long-lived assets impairment analyses are sensitive to changes in key assumptions used in our analysis, estimates of future crack spreads, forecasted production levels, operating costs and capital expenditures. If the assumptions used in our analysis are not realized, it is possible a material impairment charge may need to be recorded in the future. We cannot accurately predict the amount and timing of any additional impairments of goodwill or long-lived assets in the future.

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As market prices for refined products and market prices for crude oil continue to fluctuate, we will need to continue to evaluate the carrying value of our refinery reporting units. During the year ended December 31, 2020, we recorded long-lived asset impairment charges of $232.2 million that related to our Cheyenne Refinery, $26.5 million for construction-in-progress consisting primarily of engineering work for potential upgrades to certain processing units at our Tulsa and El Dorado Refineries and $204.7 million related to PCLI. Also, during the year ended December 31, 2020, we recorded a goodwill impairment charge of $81.9 million that related to Sonneborn. 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 asset impairments at some point in the future. Future impairment charges could be material to our results of operations and financial condition.

Potential product, service or other related liability claims and litigation could adversely affect our business, reputation and results of operations.

A significant portion of our operating responsibility on refined product pipelines is to insure the quality and purity of the products loaded at our loading racks. If our quality control measures were to fail, we may have contaminated or off-specification commingled pipelines and storage tanks or off-specification product could be sent to public gasoline stations. The development, manufacture and sale of specialty lubricant products also involves an inherent risk of exposure to potential product liability claims. These types of incidents could result in product liability claims from our customers. Our Lubricants and Specialty Products segment could also be subject to false advertising claims, product recalls, workplace exposure, product seizures and related adverse publicity.

Any of these incidents is a significant commercial risk. Substantial damage awards have been made in certain jurisdictions against manufacturers and resellers based upon claims for injuries caused by the use of or exposure to various products. There can be no assurance that product liability claims against us would not have a material adverse effect on our business, reputation or results of operations or our ability to maintain existing customers or retain new customers. Although we maintain product and other general liability insurance, there can be no assurance that the types or levels of coverage maintained are adequate to cover these potential risks, or that we will be able to continue to maintain existing insurance or obtain comparable insurance at a reasonable cost, if at all.

We sell many of our lubricants and specialty products through distributors, which presents risks that could adversely affect our operating results.

A large portion of our lubricants and specialty product sales, both in domestic and international markets, occur through distributors. As a result, we are dependent on these distributors to promote and create demand for our products. We cannot assure you that we will be successful in maintaining and strengthening our relationships with our distributors or establishing relationships with new distributors who have the ability to market, sell and support our products effectively. We may rely on one or more key distributors for a product or a region, and the loss of these distributors could reduce our revenue. The sales, business practices and reputation of our distributors may affect our business and our reputation. The consolidation of distributors, loss of a relationship with a distributor, significant disagreement with a distributor, or significant deterioration in the financial condition of a distributor could also have an adverse effect on our operating results and may also result in increased competition in the applicable jurisdiction.

Our hedging transactions may limit our gains and expose us to other risks.

We periodically enter into derivative transactions as it relates to inventory levels and/or future production to manage the risks from changes in the prices of crude oil, refined products and other feedstocks. These transactions limit our potential gains if commodity prices move above or below the certain price levels established by our hedging instruments. We hedge price risk on inventories above our target levels to minimize the impact these price fluctuations have on our earnings and cash flows. Consequently, our hedging results may fluctuate significantly from one reporting period to the next depending on commodity price fluctuations and our relative physical inventory positions. These transactions may also expose us to risks of financial losses; for example, if our production is less than we anticipated at the time we entered into a hedge agreement or if a counterparty to our hedge agreements fails to perform its obligations under the agreements.

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RISKS RELATED TO GOVERNMENT REGULATION

There are various risks associated with greenhouse gases and climate change that could result in increased operating costs and litigation and reduced demand for the refined products we produce and investment in our industry.

Climate change continues to attract considerable attention in the United States, Canada, Europe, and other regions. Numerous proposals have been made and could continue to be made at the international, national, regional and state levels of government to monitor and limit existing emissions of greenhouse gases, or “GHGs”, to restrict or eliminate such future emissions, and to require or incentivize the use of lower-carbon or renewable alternatives. As a result, our operations are subject to a series of regulatory, political, litigation, and financial risks associated with the refining of petroleum products and emission of GHGs.

The EPA has determined that emissions of carbon dioxide, methane and other GHGs present an endangerment to public health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth's atmosphere and other climatic changes. The U.S. Supreme Court has also found that GHG emissions constitute a pollutant under the CAA. Accordingly, the EPA has adopted rules that, among other things, establish construction and operating permit reviews for GHG emissions from certain large stationary sources, require the monitoring and annual reporting of GHG emissions from certain petroleum and natural gas sources in the United States or to control or reduce emissions of GHGs, including methane, from such sources. In addition, the EPA, together with the DOT, implement GHG emission and corporate average fuel economy standards for vehicles manufactured in the United States. Moreover, on January 27, 2021, President Biden issued an executive order that commits to substantial action on climate change, calling for, among other things, the increased use of zero-emissions vehicles by the federal government, the elimination of subsidies provided to the fossil fuel industry, and increased emphasis on climate-related risks across governmental agencies and economic sectors. Additionally, various states and groups of states have adopted or are considering adopting legislation, regulations or other regulatory initiatives that are focused on such areas as GHG cap and trade programs, carbon taxes, reporting and tracking programs, restriction of emissions, electric vehicle mandates and combustion engine phaseouts. Similar such regulations exist at the provincial and federal levels in Canada, including a nation-wide greenhouse gas pricing initiative and regulations related to the control of GHGs from automobiles and light duty trucks and either cap and trade programs or carbon taxes in the provinces of Quebec, Ontario, and Alberta. The Netherlands also participates in certain European legal initiatives, including GHG cap and trade programs, and the Climate Act with the goal of significantly reducing GHG emissions by 49% (compared to 1990) by 2030 and by at least 95% (compared to 1990) by 2050. The Climate Act also establishes that the government must prepare a Climate Plan. The first Climate Plan covers the period between 2021 and 2030. This plan contains, amongst others, the principles by which the government intends to achieve the goals set out in the Climate Act. It is unclear what further measures the Dutch government will take to reduce GHG emissions pursuant to this law. At the international level, the United Nations-sponsored “Paris Agreement” calls for member nations to limit their GHG emissions through nationally-determined reduction goals reevaluated every five years after 2020. The United States initially joined and then withdrew from such agreement, effective November 4, 2020. Under the new administration, the United States rejoined the agreement effective February 19, 2021 and has instructed the federal government to begin formulating the United States' emissions reduction goal. EU member states have agreed to reduce emissions by at least 40% by 2030. The Netherlands target is 49% reduction in GHG emissions by 2030.

The adoption of legislation or regulatory programs to reduce emissions of GHGs could require us to incur increased operating costs, such as costs to purchase and operate emissions control systems, to acquire emissions allowances or comply with new regulatory or reporting requirements. Any such legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for, the refined products that we produce. Additionally, political, litigation and financial risks may result in curtailed refinery activity, incurred liability, or other adverse effects on our business, financial condition and results of operations.

There are also increasing risks of litigation related to climate change effects. Governments and third-parties have brought suit against some fossil fuel companies alleging, among other things, that such companies created public and private nuisances by producing fuels that contributed to climate change, such as rising sea levels, and therefore are responsible for roadway and infrastructure damages as a result, or alleging that the companies have been aware of the adverse effects of climate change for some time but defrauded their investors or customers by failing to adequately disclose those impacts. While we are not party to such suits at this time, we may become subject to such litigation in the future. Such cases could also adversely impact public perception and the demand for fossil fuels and petroleum products, which could subsequently result in decreased demand for our services and refined products and a drop in our share price.

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Our share price could be adversely impacted if existing shareholders, including institutional investors, elect in the future to shift some or all of their investments into renewable energy or non-energy related sectors based on social and environmental considerations. Additionally, in recent years institutional lenders have become more attentive to sustainable lending practices and have been lobbied intensively, and often publicly, by environmental activists, proponents of the international Paris Agreement, and foreign citizenry concerned about climate change not to provide funding for fossil fuel energy companies. Limitation of investments in and financings for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development or production activities, could result in a reduction of available capital funding for potential development projects and could also adversely affect demand for our services and refined products, all of which could impact our future financial results.

The availability and cost of renewable identification numbers and other required credits could have an adverse effect on our financial condition and results of operations.

Pursuant to the 2007 Energy Independence and Security Act, the EPA promulgated the RFS regulations reflecting the increased 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 RINs, in lieu of such blending. We currently purchase RINs for some fuel categories on the open market in order to comply with the quantity of renewable fuels we are required to blend under the RFS regulations. Since the EPA first began mandating biofuels in excess of the “blend wall” (the 10% ethanol limit prescribed by most automobile warranties), the price of RINs has been extremely volatile. While we cannot predict the future prices of RINs, the costs to obtain the necessary number of RINs could be material. If we are unable to pass the costs of compliance with the RFS regulations on to our customers, if sufficient RINs are unavailable for purchase, if we have to pay a significantly higher price for RINs or if we are otherwise unable to meet the RFS mandates, our financial condition and results of operations could be adversely affected.

In the past, we have received small refinery exemptions under the RFS program for certain of our refineries. However, there is no assurance that such an exemption will be obtained for any of our refineries in future years. For example, the EPA has recently indicated it plans to more closely align the agency’s criteria for granting small refinery exemptions with the recommendation of the Department of Energy, which could result in fewer such exemptions being granted. The failure to obtain such exemptions for certain of our refineries could result in the need to purchase more RINs than we currently have estimated and accrued for in our consolidated financial statements. EPA recently promulgated new RFS regulations that could require the agency to increase the volume of renewable fuel or RINs that refiners are required to purchase if the agency anticipates it will grant small refinery exemptions. This also could increase the number of RINs we need to purchase. Additionally, a recent decision by the U.S. Court of Appeals for the 10th Circuit vacated two small refinery exemption decisions for the 2016 compliance year and remanded the case to the EPA for further proceedings. That decision is before the Supreme Court for further review. 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.

In addition, the RFS regulations are highly complex and evolving, requiring us to periodically update our compliance systems. The RFS regulations require the EPA to determine and publish the applicable annual volume and percentage standards for each compliance year by November 30 for the forthcoming year, and such blending percentages could be higher or lower than amounts estimated and accrued for in our consolidated financial statements. The future cost of RINs is difficult to estimate until such time as the EPA finalizes the applicable standards for the forthcoming compliance year, but the EPA does not always do so by the statutory deadline. Moreover, in addition to increased price volatility in the RINs market, there have been multiple instances of RINs fraud occurring in the marketplace over the past several years. The EPA has initiated several enforcement actions against refiners who purchase fraudulent RINs, resulting in substantial costs to the refiner. We cannot predict with certainty our exposure to increased RINs costs in the future, nor can we predict the extent by which costs associated with RFS regulations will impact our future results of operations.

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We incur significant costs, and expect to incur additional costs in the future, to comply with existing, new and changing environmental, energy, health and safety laws and regulations, and face potential exposure for environmental matters.

Operations of our facilities and pipelines are subject to international, foreign, federal, state, provincial and local laws regulating, among other things, the generation, storage, handling, use, transportation and distribution of petroleum and hazardous substances by pipeline, truck, rail, ship and barge, the emission and discharge of materials into the environment, waste management, and characteristics and composition of gasoline and diesel fuels, and other matters otherwise relating to the protection of the environment. In addition, we have manufacturing and distribution operations in foreign countries that are subject to the environmental laws and regulations of such foreign countries. Permits or other authorizations are required under these laws for the operation of our facilities, pipelines and related operations, and these permits and authorizations are subject to revocation, modification and renewal or may require operational changes, which may involve significant costs. Furthermore, a violation of permit conditions or other legal or regulatory requirements could result in substantial fines, criminal sanctions, permit revocations, injunctions, refinery shutdowns, and reputational harm. In addition, major modifications of our operations due to changes in the law could require changes to our existing permits or expensive upgrades to our existing pollution control equipment, which could have a material adverse effect on our business, financial condition, or results of operations. For example, in October 2015, the EPA lowered the NAAQS for ozone from 75 to 70 parts per billion for both the 8-hour primary and secondary standards and, in 2018, published attainment/nonattainment designations. State implementation of the revised NAAQS could result in stricter permitting requirements, delay or prohibit our ability to obtain such permits, and result in increased expenditures for pollution control equipment, the costs of which could be significant. Also, in February 2016, a new EPA rule became effective that amends three refinery standards already in effect, imposing additional or, in some cases, new emission control requirements on subject refineries. The final rule requires, among other things, benzene monitoring at the refinery fence line and submittal of fence line monitoring data to the EPA on a quarterly basis; upgraded storage tank controls requirements, including new applicability thresholds; enhanced performance requirements for flares, continuous monitoring of flares and pressure release devices and analysis and remedy of flare release events; and compliance with emissions standards for delayed coking units. In November 2018, the EPA published amendments to the new rules to clarify and correct certain requirements. These rules, as well as subsequent rulemaking under the CAA or similar laws, or new agency interpretations of existing laws and regulations, may necessitate additional expenditures in future years and result in increased costs on our operations. Compliance with applicable environmental laws, regulations and permits will continue to have an impact on our operations, results of our operations and capital requirements.

As is the case with all companies engaged in industries similar to ours, we face potential exposure to future claims and lawsuits involving environmental matters. The matters include, but are not limited to, soil, groundwater and waterway contamination, air pollution, personal injury and property damage allegedly caused by substances which we processed, manufactured, handled, used, released or disposed.

We are and have been the subject of various local, state, provincial, federal, foreign, international and private proceedings relating to environmental regulations, conditions and inquiries. Current and future environmental regulations are expected to require additional expenditures, including expenditures for investigation and remediation, which may be significant, at our facilities. To the extent that future expenditures for these purposes are material and can be reasonably determined, these costs are disclosed and accrued.

Our operations are also subject to various foreign and domestic laws and regulations relating to occupational health and safety. We maintain safety, training and maintenance programs as part of our ongoing efforts to ensure compliance with applicable laws and regulations but cannot guarantee that these efforts will always be successful. Compliance with applicable health and safety laws and regulations has required and continues to require substantial expenditures. Failure to appropriately manage occupational health and safety risks associated with our business could also adversely impact our employees, communities, stakeholders, reputation and results of operations.

The costs of environmental and safety regulations are already significant and compliance with more stringent laws or regulations or adverse changes in the interpretation of existing regulations by government agencies or courts could have an adverse effect on the financial position and the results of our operations and could require substantial expenditures for the installation and operation of systems and equipment that we do not currently possess.

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We are also subject to existing, and may in the future be subject to new or changing, domestic and foreign energy policy legislation. For example, in the United States, the Energy Independence and Security Act mandates annually increasing levels for the use of renewable fuels such as ethanol and increasing energy efficiency goals, among other steps. Dutch law also focuses on increasing the use of renewal fuels, and in Canada, fuel content legislation exists at the federal and provincial level. These statutory mandates may have the impact over time of offsetting projected increases in the demand for refined petroleum products in certain markets, particularly gasoline. In the near term, the new renewable fuel standard presents ethanol production and logistics challenges for both the ethanol and refining industries and may require additional capital expenditures or expenses by us to accommodate increased ethanol use. Other legislative changes may similarly alter the expected demand and supply projections for refined petroleum products in ways that cannot be predicted.

For additional information on regulations and related liabilities or potential liabilities affecting our business, see “Regulation” under Items 1 and 2, “Business and Properties,” and Item 3, “Legal Proceedings.”

We are subject to significant regulation and oversight by governmental agencies.

New laws, policies, regulations, rulemaking and oversight, as well as changes to those currently in effect, could adversely impact our earnings, cash flows and operations. Our assets and operations are subject to regulation and oversight by foreign, federal, state and local regulatory authorities. Legislative changes, as well as regulatory actions taken by these agencies, have the potential to adversely affect our profitability. In addition, a certain degree of regulatory uncertainty is created by the new administration because it remains unclear specifically what the new administration may do with respect to future policies and regulations that may affect us. Regulation affects almost every part of our business. Furthermore, we could incur additional costs to comply with such statutes, rules, regulations and orders. Should we fail to comply with any applicable statutes, rules, regulations, and orders of regulatory authorities, we could be subject to substantial penalties and fines. New laws, regulations or policy changes sometimes arise from unexpected sources. New laws or regulations, unexpected policy changes or interpretations of existing laws or regulations, applicable to our income, operations, assets or another aspect of our business, could have a material adverse impact on our earnings, cash flow, financial condition and results of operations.

Our business is subject to complex and evolving global laws, regulations and security standards regarding privacy, cybersecurity and data protection (“data protection laws”). Many of these laws are subject to change and uncertain interpretation, and could result in claims, increased cost of operations, or otherwise harm our business.

The constantly evolving regulatory and legislative environment surrounding data privacy and protection poses increasingly complex compliance challenges, and complying with such data protection laws could increase the costs and complexity of compliance. While we do not collect significant amounts of personal information from consumers, we do have personal information from our employees, job applicants and some business partners, such as contractors and distributors. Any failure, whether real or perceived, by us to comply with applicable data protection laws could result in proceedings or actions against us by governmental entities or others, subject us to significant fines, penalties, judgments, and negative publicity, require us to change our business practices, increase the costs and complexity of compliance, and adversely affect our business. Our compliance with recently enacted laws like the General Data Protection Regulation, and other similar privacy/security laws, as well as any associated inquiries or investigations or any other government actions related to these laws, may increase our operating costs.

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Increases in required fuel economy and regulation of CO2 emissions from motor vehicles may reduce demand for transportation fuels.

The EPA and the National Highway Traffic Safety Administration (“NHTSA”) are required to promulgate requirements regarding the Corporate Average Fuel Economy (“CAFE”) of the nation's passenger fleet. On August 28, 2012, the EPA and NHTSA adopted standards through model year 2025 in two phases. The first phase established final standards for 2017-2021 model year vehicles that are projected to require 40.3 - 41.0 m.p.g. in model year 2021 on an average industry fleet-wide basis. The second phase of the CAFE program represents non-final “augural” standards for 2022-2025 model year vehicles that are projected to require 48.7 - 49.7 m.p.g. in model year 2025 on an average industry fleet-wide basis. However, following the change in presidential administrations, there have been attempts to modify these standards. In August 2018, the EPA and NHTSA proposed the Safer Affordable Fuel Economy Rule which amended the existing CAFE standards and proposed new standards covering model years through 2026. While the EPA issued a rule in September 2019 that seeks to preempt the ability of states to set stricter standards than those set by the federal government, no final rule has yet been issued regarding amendments to the current CAFE standards. All of these rulemakings will likely be subject to challenge by a variety of parties seeking stricter GHG and CAFE standards. Additionally, several states are seeking to promote zero emission vehicles, such as electric vehicles, and to mandate transition away from internal combustion engines. Any increases in fuel economy standards, along with mandated increases in use of renewable fuels discussed above, as well as electric vehicle mandates or combustion engine bans, could result in decreasing demand for petroleum fuels. Decreasing demand for petroleum fuels could have a material effect on our financial condition and results of operation.

GENERAL RISK FACTORS

Cyberattacks or security breaches could have a material adverse effect on our business, financial condition and results of operations.

Our business is dependent upon information systems and other digital technologies for controlling our plants and pipelines, processing transactions and summarizing and reporting results of operations. The secure processing, maintenance and transmission of information is critical to our operations. We monitor our information systems on a 24/7 basis in an effort to detect cyberattacks or security breaches. Preventative and detective measures we utilize include independent cybersecurity audits and penetration tests. We implemented these efforts along with other risk mitigation procedures to detect and address unauthorized and damaging activity on our network, stay abreast of the increasing threat landscape and improve our security posture. Information technology system failures, communications network disruptions (whether intentional by a third party or due to natural disaster), and security breaches could still impact equipment and software used to control plants and pipelines, resulting in improper operation of our assets, potentially including delays in the delivery or availability of our customers’ products, contamination or degradation of the products we transport, store or distribute, or releases of hydrocarbon products and other damage to our facilities for which we could be held liable.

Furthermore, we collect and store sensitive data in the ordinary course of our business, including personally identifiable information of our employees as well as our proprietary business information and that of our customers, suppliers, investors and other stakeholders. Despite our security measures, our information systems may become the target of cyberattacks or security breaches (including employee error, malfeasance or other breaches), which could result in the theft or loss of the stored information, misappropriation of assets, disruption of transactions and reporting functions, our ability to protect customer or company information and our financial reporting. Even with insurance coverage, a claim could be denied or coverage delayed. A cyber-attack or security breach could result in liability under data privacy laws, regulatory penalties, damage to our reputation or a loss of consumer confidence in our products and services, or additional costs for remediation and modification or enhancement of our information systems to prevent future occurrences, all of which could have a material and adverse effect on our business, financial condition or results of operations.

Our operations are subject to catastrophic losses, operational hazards and unforeseen interruptions and other disruptive risks for which we may not be adequately insured.

Our operations are subject to catastrophic losses, operational hazards, unforeseen interruptions and other disruptive risks such as natural disasters, adverse weather, accidents, maritime disasters (including those involving marine vessels/terminals), fires, explosions, hazardous materials releases, terror or cyberattacks, domestic vandalism, power failures, mechanical failures and other events beyond our control. These events could result in an injury, loss of life, property damage or destruction, as well as a curtailment or an interruption in our operations and may affect our ability to meet marketing commitments.

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We may not be able to maintain or obtain insurance of the type and amount we desire at commercially reasonable rates and exclusions from coverage may limit our ability to recover the amount of the full loss in all situations. As a result of market conditions, premiums and deductibles for certain of our insurance policies could increase. In some instances, certain insurance could become unavailable or available only for reduced amounts of coverage.

There can be no assurance that insurance will cover all or any damages and losses resulting from these types of hazards. We are not fully insured against all risks to our business and therefore, we self-insure certain risks. If any of our facilities were to experience an interruption in operations, our earnings could be materially adversely affected (to the extent not recoverable through insurance) because of lost production and repair costs.

The energy industry is highly capital intensive, and the entire or partial loss of individual facilities can result in significant costs to both industry companies, such as us, and their insurance carriers. In recent years, several large energy industry claims have resulted in significant increases in the level of premium costs and deductible periods for participants in the energy industry. As a result of large energy industry claims, insurance companies that have historically participated in underwriting energy-related facilities may discontinue that practice or demand significantly higher premiums or deductible periods to cover these facilities. If significant changes in the number or financial solvency of insurance underwriters for the energy industry occur, or if other adverse conditions over which we have no control prevail in the insurance market, we may be unable to obtain and maintain adequate insurance at reasonable cost. In addition, we cannot assure you that our insurers will renew our insurance coverage on acceptable terms, if at all, or that we will be able to arrange for adequate alternative coverage in the event of non-renewal. Further, our underwriters could have credit issues that affect their ability to pay claims. If a significant accident or event occurs that is self-insured or not fully insured, it could have a material adverse effect on our business, financial condition and results of operations.

We may be subject to information technology system failures, communications network disruptions and data breaches.

We depend on the efficient and uninterrupted operation of hardware and software systems and infrastructure, including our operating, communications and financial reporting systems. These systems are critical in meeting customer expectations, effectively tracking, maintaining and operating our equipment, directing and compensating our employees, and interfacing with our financial reporting system. We have implemented safeguards and other preventative measures to protect our systems and data, including sophisticated network security and internal control measures; however, our information technology systems and communications network, and those of our information technology and communication service providers, remain vulnerable to interruption by fire, earthquake, power loss, telecommunications failure, terrorist attacks, Internet failures, computer malware, cyberattacks, data breaches and other events unforeseen or generally beyond our control.

We may not be able to obtain funding on acceptable terms or at all because of volatility and uncertainty in the credit and capital markets. This may hinder or prevent us from meeting our future capital needs.

The domestic and global financial markets and economic conditions are disrupted and volatile from time to time due to a variety of factors, including low consumer confidence, high unemployment, geoeconomic and geopolitical issues, weak economic conditions and uncertainty in the financial services sector. In addition, the fixed-income markets have experienced periods of extreme volatility, which negatively impacted market liquidity conditions. Recently, the equity and debt markets for many energy industry companies have been adversely affected by low oil prices. As a result, the cost of raising money in the debt and equity capital markets has increased substantially at times while the availability of funds from these markets diminished significantly. In particular, as a result of concerns about the stability of financial markets generally and the solvency of lending counterparties specifically, the cost of obtaining money from the credit markets may increase as many lenders and institutional investors increase interest rates, enact tighter lending standards, refuse to refinance existing debt on similar terms or at all and reduce, or in some cases cease to provide, funding to borrowers. In addition, lending counterparties under any existing revolving credit facility and other debt instruments may be unwilling or unable to meet their funding obligations, or we may experience a decrease in our capacity to issue debt or obtain commercial credit or a deterioration in our credit profile, including a rating agency lowering or withdrawing of our credit ratings if, in its judgment, the circumstances warrant. Due to these factors, we cannot be certain that new debt or equity financing will be available on acceptable terms. If funding is not available when needed, or is available only on unfavorable terms, we may be unable to meet our obligations as they come due or we may be required to sell assets. Moreover, without adequate funding, we may be unable to execute our growth strategy, complete future acquisitions or construction projects, take advantage of other business opportunities or respond to competitive pressures, comply with regulatory requirements, or meet our short-term or long-term working capital requirements, any of which could have a material adverse effect on our revenues and results of operations. Failure to comply with regulatory requirements in a timely manner or meet our short-term or long-term working capital requirements could subject us to regulatory action.
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Our business is subject to the risks of international operations, including currency fluctuations

We derive a portion of our revenue and earnings from international operations. Our acquisitions of Petro-Canada Lubricants and Sonneborn have expanded our operations and sales in foreign countries and correspondingly may increase our exposure to foreign exchange risks. Any significant change in the value of the currencies of the countries in which we do business against the U.S. dollar could affect our revenue, competitiveness and cost of doing business, which could have a material adverse effect on our business, financial condition and results of operations.

In addition, compliance with applicable U.S. and foreign laws and regulations, such as import and export requirements, anti-corruption laws, data privacy regulations and foreign exchange controls and cash repatriation restrictions, environmental laws, labor laws and anti-competition regulations, increases the cost of doing business in foreign jurisdictions. Although we have implemented policies and procedures to comply with these laws and regulations, a violation by any of our employees, contractors, distributors or agents could nevertheless occur. In some cases, compliance with the laws and regulations of one country could violate the laws and regulations of another country. Violations of these laws and regulations could materially adversely affect our company's brand, international growth efforts and business.

In addition, global market risks, actions by foreign nations and other international conditions, particularly in a time of increasing economic and global instability, may have a material adverse effect on our results and operations. The consequences of such uncertainty cannot be anticipated or quantified.

We are exposed to the credit risks, and certain other risks, of our key customers and vendors.

We are subject to risks of loss resulting from nonpayment or nonperformance by our customers. We derive a significant portion of our revenues from contracts with key customers.

If any of our key customers default on their obligations to us, our financial results could be adversely affected. Furthermore, some of our customers may be highly leveraged and subject to their own operating and regulatory risks. In addition, nonperformance by vendors who have committed to provide us with products or services could result in higher costs or interfere with our ability to successfully conduct our business.

Any substantial increase in the nonpayment and/or nonperformance by our customers or vendors could have a material adverse effect on our results of operations and cash flows.

Terrorist attacks, and the threat of terrorist attacks or domestic vandalism, have resulted in increased costs to our business. Continued global hostilities or other sustained military campaigns may adversely impact our results of operations.

The long-term impacts of terrorist attacks and the threat of future terrorist attacks on the energy transportation industry in general, and on us in particular, are unknown. Increased security measures taken by us as a precaution against possible terrorist attacks or domestic vandalism have resulted in increased costs to our business. Uncertainty surrounding continued global hostilities or other sustained military campaigns, and the possibility that infrastructure facilities could be direct targets of, or indirect casualties of, an act of terror, may affect our operations in unpredictable ways, including disruptions of crude oil supplies and markets for refined products. In addition, disruption or significant increases in energy prices could result in government-imposed price controls. Any one of, or a combination of, these occurrences could have a material adverse effect on our business, financial condition and results of operations.

Changes in the insurance markets attributable to terrorist attacks and domestic vandalism could make certain types of insurance more difficult for us to obtain. Moreover, the insurance that may be available to us may be significantly more expensive than our existing insurance coverage. Instability in the financial markets as a result of terrorism, vandalism or war could also affect our ability to raise capital including our ability to repay or refinance debt.

We may be unable to pay future dividends.

We will only be able to pay dividends from our available cash on hand, cash from operations or borrowings under our credit agreement. The declaration of future dividends on our common stock is evaluated quarterly and will be at the discretion of our board of directors and will depend upon many factors, including our results of operations, financial condition, earnings, capital requirements, and restrictions in our debt agreements and legal requirements. We cannot assure you that any dividends will be paid or the frequency or amounts of such payments.
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We may be unable to adequately protect our intellectual property, which may increase our cost of doing business or otherwise hurt our ability to compete in the market.

We use intellectual property in the ordinary course of our business, including trademarks, trade secrets, copyrighted work and innovations, some of which is material to our business. We take measures to identify and protect our intellectual property through practices appropriate for securing and protecting exclusive rights in and to our intellectual property, including applying for registrations in the United States and in various foreign countries. Despite our efforts to protect such intellectual property, it is possible that competitors or other unauthorized third parties may obtain, copy, use or disclose our trademarks (or other marks likely to cause confusion among our consumers), technologies, products and processes. In addition, the laws and/or judicial systems and enforcement mechanisms of foreign countries in which we create, market and sell our products may afford little or no effective protection of our intellectual property. We may also be subject to infringement complaints from others challenging our use of a technology. We cannot guarantee that our efforts to enforce our intellectual property rights against unauthorized use and appropriation, or our efforts to defend against third party claims of infringement would be successful. These potential risks to our intellectual property could subject us to increased competition and negatively impact our liquidity, financial position and results of operations.

Changes in our credit profile, or a significant increase in the price of crude oil, may affect our relationship with our suppliers, which could have a material adverse effect on our liquidity and limit our ability to purchase sufficient quantities of crude oil to operate our refineries at desired capacity.

An unfavorable credit profile, or a significant increase in the price of crude oil, could affect the way crude oil suppliers view our ability to make payments and induce them to shorten the payment terms of their invoices with us or require credit enhancement. Due to the large dollar amounts and volume of our crude oil and other feedstock purchases, any imposition by our suppliers of more burdensome payment terms or credit enhancement requirements on us may have a material adverse effect on our liquidity and our ability to make payments to our suppliers. This in turn could cause us to be unable to operate our refineries at desired capacity. A failure to operate our refineries at desired capacity could adversely affect our profitability and cash flow.

Our credit facility contains certain covenants and restrictions that may constrain our business and financing activities.

The operating and financial restrictions and covenants in our credit facility and any future financing agreements could adversely affect our ability to finance future operations or capital needs or to engage, expand or pursue our business activities. For example, our revolving credit facility imposes usual and customary requirements for this type of credit facility, including: (i) limitations on liens and indebtedness; (ii) a prohibition on changes in control and (iii) restrictions on engaging in mergers and consolidations. If we fail to satisfy the covenants set forth in the credit facility or another event of default occurs under the credit facility, the maturity of the loan could be accelerated or we could be prohibited from borrowing for our future working capital needs and issuing letters of credit. We might not have, or be able to obtain, sufficient funds to make these immediate payments. If we desire to undertake a transaction that is prohibited by the covenants in our credit facility, we will need to obtain consent under our credit facility. Such refinancing may not be possible or may not be available on commercially acceptable terms.

Our business may suffer due to a departure of any of our key senior executives or other key employees. Furthermore, a shortage of skilled labor may make it difficult for us to maintain labor productivity.

Our future performance depends to a significant degree upon the continued contributions of our senior management team and key technical personnel. We do not currently maintain key person life insurance, non-compete agreements, or employment agreements with respect to any member of our senior management team. The loss or unavailability to us of any member of our senior management team or a key technical employee could significantly harm us. We face competition for these professionals from our competitors, our customers and other companies operating in our industry. To the extent that the services of members of our senior management team and key technical personnel would be unavailable to us for any reason, we may be required to hire other personnel to manage and operate our company. We may not be able to locate or employ such qualified personnel on acceptable terms, or at all.

Furthermore, our operations require skilled and experienced laborers with proficiency in multiple tasks. A shortage of trained workers due to retirements or otherwise could have an adverse impact on our labor productivity and costs and our ability to expand production in the event there is an increase in the demand for our products and services, which could adversely affect our operations.

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A portion of our workforce is unionized, and any disruptions in our labor force or adverse employee relations could adversely affect our business.

We depend on unionized labor for the operation of many of our facilities. As of December 31, 2020, approximately 29% of our employees were represented by labor unions under collective bargaining agreements with various expiration dates. In addition, employees who are not currently represented by labor unions may seek union representation in the future. We may not be able to renegotiate our collective bargaining agreements when they expire on satisfactory terms or at all. If we are unable to renegotiate our collective bargaining agreements when they expire, any work stoppages or other labor disturbances at these facilities could have an adverse effect on our business, impact our ability to make distributions to our unitholders and payments of our debt obligations, and increase our costs. In addition, our existing labor agreements may not prevent a strike or work stoppage or other adverse employee relations event at any of our facilities in the future, and any work stoppage could negatively affect our results of operations and financial condition.

The market price of our common stock may fluctuate significantly, and the value of a stockholder’s investment could be impacted.

The market price of our common stock may be influenced by many factors, some of which are beyond our control, including:

our quarterly or annual earnings or those of other companies in our industry;
changes in accounting standards, policies, guidance, interpretations or principles;
general economic, industry global and stock market conditions;
the failure of securities analysts to cover our common stock or changes in financial estimates by analysts;
future sales of our common stock;
announcements by us or our competitors of significant contracts or acquisitions;
sales of common stock by us, our senior officers or our affiliates; and/or
the other factors described in these Risk Factors.

In recent years, the stock market has experienced extreme price and volume fluctuations. This volatility has had a significant impact on the market price of securities issued by many companies, including companies in our industry. The price of our common stock could fluctuate based upon factors that have little or nothing to do with our company, and these fluctuations could materially reduce our stock price.

Compliance with and changes in tax laws could materially and adversely impact our financial condition, results of operations and cash flows.

We are subject to extensive tax liabilities, including federal and state income taxes and transactional taxes such as excise, sales and use, payroll, franchise, withholding and property taxes. New tax laws and regulations and changes in existing tax laws and regulations could result in increased expenditures by us for tax liabilities in the future and could materially and adversely impact our financial condition, results of operations and cash flows.

Additionally, many tax liabilities are subject to periodic audits by taxing authorities, and such audits could subject us to interest and penalties.


Item 1B. Unresolved Staff Comments

We do not have any unresolved staff comments.


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Item 3.    Legal Proceedings

Commitment and Contingency Reserves

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 when a governmental authority is party to the proceedings and such proceedings involve potential monetary sanctions that we reasonably believe could exceed $300,000 or more. Certain disclosures made under the SEC’s prior $100,000 threshold will remain until their resolution.

Environmental Matters

Our respective subsidiaries have or will develop corrective action plans regarding these disclosures that will be implemented in consultation with the respective federal and state agencies. It is not possible to predict the ultimate outcome of these proceedings, although none are currently expected to have a material effect on our financial condition, results of operations or cash flows.

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 alleged violations of air quality emission 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 the WDEQ entered into a consent decree, and on August 9, 2019, HFCR paid 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. HFCR and WDEQ have been in discussions to resolve WDEQ’s alleged violations of air quality limits that occurred during the third quarter of 2017 through calendar year 2019. The WDEQ and HFCR also previously agreed that the discussions would also include exceedances that occurred during the first quarter of 2020 through the cessation of petroleum refining operations at the Cheyenne Refinery in the third quarter of 2020. During a settlement conference on November 9, 2020, WDEQ proposed a settlement that would impose a penalty of $95,075 to resolve the alleged violations that occurred during the third quarter of 2017 through the date of the refinery shutdown. As part of the settlement process, on January 15, 2021, the State of Wyoming filed a complaint with the Wyoming District Court addressing the alleged violations. The WDEQ and HFCR agreed on the terms of a consent decree to resolve the alleged violations, and on February 18, 2021, a Joint Motion for Entry of Consent Decree and the Consent Decree were filed with the Wyoming District Court. HFCR expects that the Wyoming District Court will enter the Consent Decree during the first quarter of 2021.

El Dorado
HollyFrontier El Dorado Refining LLC (“HFEDR”) has been engaged in discussions with, and has responded to document requests from, the EPA, the U.S. Department of Justice (“DOJ”) and the State of Kansas regarding alleged Clean Air Act civil violations relating to flaring devices and other equipment at the refinery. Topics of the discussions included: (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.

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, and on August 27, 2020, the consent decree was entered by the district judge and became effective. 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 is 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 initial payment of $1 million each was paid to the EPA on September 18, 2020 and the State of Kansas on September 22, 2020, and HFEDR has undertaken several of the required projects. The consent decree resolves 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 was terminated.

The Occupational Safety and Health Administration (“OSHA”) conducted investigations into both the September 2017 and March 2019 events identified above, and HFEDR settled the OSHA claims related to 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.

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. On April 3, 2019, the EPA notified HFTR of potential violations of the Consent Decrees. On December 1, 2020, ODEQ, on behalf of ODEQ and the EPA, issued two demand letters alleging violations under the Consent Decrees, which stemmed from inspections conducted by the EPA at the refineries from May 1 through 5, 2017, as well as from a review of the refineries’ records. The alleged violations included the failure to comply with applicable continuous emissions monitoring system (CEMS) requirements and exceedances of the hydrogen sulfide (H2S) emission limits. During a follow-up conference call with ODEQ, on January 6, 2021, ODEQ shared its stipulated penalty amounts for alleged violations pursuant to the two Consent Decrees. HFTR submitted timely responses to the ODEQ demand letters on February 8, 2021. It is too soon to predict the outcome of this matter.

Woods Cross
HollyFrontier Woods Cross Refining LLC (“HFWCR”) operates under a federal consent decree with the EPA and the Utah Department of Environmental Quality. On November 3, 2020, HFWCR received a letter from the EPA identifying potential violations of HFWCR’s federal consent decree that occurred from calendar year 2015 through the date of the letter. HFWCR provided a response letter to the EPA on December 3, 2020 disputing certain of the potential violations in the EPA's November 3, 2020 letter, and HFWCR supplemented its response letter on February 5, 2021 with additional information. It is too soon to predict the outcome of this matter.

Federal Trade Commission

On July 23, 2019, the Federal Trade Commission (“FTC”) issued a Civil Investigative Demand and a related Subpoena Duces Tecum requesting we provide specified information relating to the Sonneborn acquisition that closed on February 1, 2019.

We cooperated with the FTC in its investigation. On December 2, 2020, the FTC notified us that no further action was warranted, and it had closed the investigation.

Renewable Fuel Standard

Various subsidiaries of HollyFrontier are currently intervenors in three 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.

On January 24, 2020, in the first of these lawsuits, 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 April 15, 2020, the Tenth Circuit entered its mandate, remanding the matter back to the EPA. On September 4, 2020, various subsidiaries of HollyFrontier filed a Petition for a Writ of Certiorari with the U.S. Supreme Court appealing the Tenth Circuit decision. On
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January 8, 2021, the U.S. Supreme Court granted HollyFrontier’s petition. We anticipate decision from the Supreme Court in June 2021. We expect that we will not know what steps the EPA will take with respect to our 2016 small refinery exemptions or how the case will impact future small refinery exemptions until after the Supreme Court’s decision in this matter.

The second lawsuit is before the Tenth Circuit. The matter is fully briefed and remains pending before that court.

The third lawsuit is before the DC Circuit. Briefing of the issues before the court commenced on December 7, 2020; however, in light of the Supreme Court’s decision to hear HollyFrontier’s appeal of the Tenth Circuit decision, this case was stayed pending a decision from the Supreme Court.

In December 2020, various subsidiaries of HollyFrontier also filed a petition for review in the DC Circuit challenging EPA’s denial of small refinery exemption petitions for years prior to 2016. The petition was consolidated with petitions from eight other refining companies challenging the same decision. In light of the Supreme Court’s decision to hear HollyFrontier’s appeal of the Tenth Circuit decision, this case was stayed pending a decision from the Supreme Court.

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 4.Mine Safety Disclosures

Not Applicable.

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PART II

Item 5.Market for the Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Our common stock is traded on the New York Stock Exchange under the trading symbol “HFC.”

In November 2019, our Board of Directors approved a $1.0 billion share repurchase program, which replaced all existing share repurchase programs. The timing and amount of stock repurchases will depend on market conditions and corporate, regulatory and other relevant considerations. We do not intend to repurchase common stock under our $1.0 billion share repurchase program until commodity prices and demand for products normalize. This program may be discontinued at any time by the Board of Directors. The following table includes repurchases made under this program during the fourth quarter of 2020.

PeriodTotal 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
October 2020— $— — $1,000,000,000 
November 2020— $— — $1,000,000,000 
December 2020— $— — $1,000,000,000 
Total for October to December 2020— — 

As of February 16, 2021, we had approximately 101,664 stockholders, including beneficial owners holding shares in street name.

We intend to consider the declaration of a dividend on a quarterly basis, although there is no assurance as to future dividends since they are dependent upon future earnings, capital requirements, our financial condition and other factors.


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Item 6.Selected Financial Data

The following table shows our selected financial information as of the dates or for the periods indicated. This table should be read in conjunction with Item 7, “Management's Discussion and Analysis of Financial Condition and Results of Operations” and our consolidated financial statements and related notes thereto included elsewhere in this Annual Report on Form 10-K.

Years Ended December 31,
20202019201820172016
(In thousands, except per share data)
FINANCIAL DATA
For the period
Sales and other revenues$11,183,643 $17,486,578 $17,714,666 $14,251,299 $10,535,700 
Income (loss) before income taxes(747,046)1,171,504 1,524,467 868,863 (171,534)
Income tax expense (benefit)(232,147)299,152 347,243 (12,379)19,411 
Net income (loss)(514,899)872,352 1,177,224 881,242 (190,945)
Less net income attributable to noncontrolling interest86,549 99,964 79,264 75,847 69,508 
Net income (loss) attributable to HollyFrontier stockholders
$(601,448)$772,388 $1,097,960 $805,395 $(260,453)
Earnings (loss) per share - basic$(3.72)$4.64 $6.25 $4.54 $(1.48)
Earnings (loss) per share - diluted$(3.72)$4.61 $6.19 $4.52 $(1.48)
Cash dividends declared per common share$1.40 $1.34 $1.32 $1.32 $1.32 
Average number of common shares outstanding:
Basic161,983 166,287 175,009 176,174 176,101 
Diluted161,983 167,385 176,661 177,196 176,101 
Net cash provided by operating activities$457,931 $1,548,611 $1,554,416 $951,390 $606,948 
Net cash used for investing activities$(330,162)$(972,914)$(360,520)$(959,670)$(801,597)
Net cash provided by (used for) financing activities$353,226 $(848,255)$(664,328)$(72,630)$838,695 
At end of period
Cash, cash equivalents and investments in marketable securities
$1,368,318 $885,162 $1,154,752 $630,757 $1,134,727 
Working capital$1,935,605 $1,620,261 $2,128,224 $1,640,118 $1,767,780 
Total assets$11,506,864 $12,164,841 $10,994,601 $10,692,154 $9,435,661 
Total debt$3,142,718 $2,455,640 $2,411,540 $2,498,993 $2,235,137 
Total equity$5,722,203 $6,509,426 $6,459,059 $5,896,940 $5,301,985 



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Item 7.Management’s Discussion and Analysis of Financial Condition and Results of Operations

This Item 7 contains “forward-looking” statements. See “Forward-Looking Statements” at the beginning of this Annual Report on Form 10-K. 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 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 an independent petroleum refiner and marketer that produces high-value light products such as gasoline, diesel fuel, jet fuel, specialty lubricant products and specialty and modified asphalt. We own and operate refineries located in Kansas, Oklahoma, New Mexico and Utah and 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.

In the third quarter of 2020, we permanently ceased petroleum refining operations at our Cheyenne Refinery and subsequently began converting certain assets at our Cheyenne Refinery to renewable diesel production. This decision was primarily based on a positive outlook in 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 EPA’s small refinery exemption. 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 long-lived asset impairment charges of $232.2 million related to our Cheyenne Refinery asset group. In connection with the cessation of petroleum refining operations at our Cheyenne Refinery, we recognized $24.7 million in decommissioning expense for the year ended December 31, 2020. In addition, for the year ended December 31, 2020, we recorded a reserve of $9.0 million against our repair and maintenance supplies inventory and $3.8 million in employee severance costs related to the conversion of our Cheyenne Refinery to renewable diesel production. These decommissioning, inventory reserve and severance costs were recognized in operating expenses, of which $24.8 million was recorded in our Refining segment and $12.7 million was recorded in our Corporate and Other segment.

During the second quarter of 2020, we also 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.

During the first quarter of 2021, we initiated a restructuring within our Lubricants and Specialty Products segment, which is expected to save approximately $15 million per year of ongoing cash expenses. Over the next twelve months, we anticipate pre-tax costs of $8 -$10 million for severance obligations.

On November 12, 2018, we entered into an equity purchase agreement to acquire 100% of the issued and outstanding capital stock of 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, a privately-owned lubricants company. The acquisition closed on August 1, 2018. Cash consideration paid was $54.2 million. Red Giant Oil is one 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 and Wyoming, along with a blending and packaging facility in Texas.

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For the year ended December 31, 2020, net loss attributable to HollyFrontier stockholders was $(601.4) million compared to net income of $772.4 million and $1,098.0 million for the years ended December 31, 2019, and 2018, respectively. Overall gross refining margins per produced barrel sold for 2020 decreased 54% over the year ended December 31, 2019 due to lower crack spreads and crude oil basis differentials. Included in our financial results for the year ended December 31, 2020 were non-cash items consisting of goodwill and long-lived asset impairment charges.

Pursuant to the 2007 Energy Independence and Security Act, the EPA promulgated the 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 RINs, in lieu of such blending. Compliance with RFS regulations significantly increases our cost of products sold, with RINs costs totaling $148.5 million for the year ended December 31, 2020.

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. Following a rebound in the late second and third quarters, demand for transportation fuels continued to be weak compared to 2019. In response to this level of demand, during the fourth quarter of 2020, we operated our Refining segment refineries at an average crude charge of 379,910 BPD.

In our Lubricants and Specialty Products segment, the Rack Forward portion saw improvement in industrial and transportation-related end markets, which drove higher demand and unit margins during the second half of 2020. Within the Rack Back portion, demand for base oils increased to 2019 levels while supply was limited due to a number of factors, which drove higher margins and utilization at our facilities in the third quarter.

The stabilization of demand drove a broad increase in commodity prices, resulting in values for our inventories held at December 31, 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 $149.2 million for the three months ended December 31, 2020. We also drew down on our inventory levels to better manage working capital in the fourth quarter of 2020, which resulted in a $35 million increase in cost of products sold for the quarter.

Our standalone (excluding HEP) liquidity was approximately $2,696.3 million at December 31, 2020, consisting of cash and cash equivalents of $1,346.3 million and an undrawn $1.35 billion credit facility maturing in 2022. Our standalone (excluding HEP) long-term debt was $1.75 billion as of December 31, 2020, which consists of $350.0 million in 2.625% senior notes due in 2023, $1.0 billion of 5.875% senior notes due in 2026 and $400.0 million in 4.500% senior notes due in 2030.


OUTLOOK

The impact of the COVID-19 pandemic on the global macroeconomy created an unprecedented reduction in demand in the first half of 2020, as well as a lack of forward visibility, for many of the transportation fuels, lubricants and specialty products and the associated transportation and terminal services we provide. We have seen improvement in demand for these products and services since the initial wave of COVID-19 infections during the second quarter of 2020, and with the increasing availability of vaccines, we believe there is a path to a fulsome recovery in demand in 2021.

In response to the COVID-19 pandemic, and with the health and safety of our employees as a top priority, we continue a range of initiatives, including limiting onsite staff at all of our facilities, implementing 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 first quarter of 2021, we expect to run between 350,000-380,000 barrels per day of crude oil. In addition to continued weakness in demand resulting from the COVID-19 pandemic, the crude charge in the first quarter of 2021 has also been adversely impacted by scheduled maintenance at our Tulsa West and Woods Cross refineries as well as reduced availability, and an increase in the price, of natural gas due to the recent extreme cold weather throughout the Mid-Continent and Southwest. We expect to adjust refinery production levels commensurate with market demand.

Within our Lubricants and Specialty Products segment, we expect a normal seasonal rebound in the first quarter of 2021. However, we do not have enough visibility to issue forward guidance at this time. Similar to our Refining segment, we expect to adjust production levels commensurate with market demand.

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At HEP, we expect to see demand for transportation and terminal services grow with underlying demand for transportation fuels and crude oil. In 2021, HEP expects to hold the quarterly distribution constant at $0.35 per unit, or $1.40 on an annualized basis. HEP remains committed to its distribution strategy focused on funding all capital expenditures and distributions within free cash flow and maintaining distributable cash flow coverage of 1.3x or greater with the goal of reducing leverage to 3.0-3.5x.

During the third quarter of 2020, we increased our liquidity by $750.0 million with the issuance of $350.0 million in 2.625% senior notes due in 2023 and $400.0 million in 4.500% senior notes due in 2030. This additional liquidity may be used for general corporate purposes and is expected to support the planned growth of our renewables business and the unexpected economic impact of COVID-19, as needed. We do not intend to repurchase common stock under our $1.0 billion share repurchase program until 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 form of tax changes, loans and grants, among others. At this time, we have not sought relief in the form 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 do so. We anticipate $50.0 million to $60.0 million in cash tax benefit in 2021 from the loss carryback potential under the CARES Act. As a result of the net operating loss incurred in the year ended December 31, 2020, we will also file refund claims of approximately $21.0 million to recover estimated tax payments made during the year.

The extent to which our future results are affected by the COVID-19 pandemic will depend on various factors and consequences beyond our control, such as the duration and scope of the pandemic, additional actions by businesses and governments in response to the pandemic and the speed and effectiveness of responses to combat the virus. The COVID-19 pandemic, and the volatile regional and global economic conditions stemming from it, could also exacerbate the risk factors identified in this Form 10-K under “Risk Factors” in Item 1A. The COVID-19 pandemic may also materially adversely affect our results in a manner that is either not currently known or that we do not currently consider to be a significant risk to our business.

A more detailed discussion of our financial and operating results for the years ended December 31, 2020 and 2019 is presented in the following sections. Discussions of year-over-year comparisons for 2019 and 2018 can be found in “Management's Discussion and Analysis of Financial Condition and Results of Operations” in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2019.


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RESULTS OF OPERATIONS

Financial Data
Years Ended December 31,
202020192018
(In thousands, except per share data)
Sales and other revenues$11,183,643 $17,486,578 $17,714,666 
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization):
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)
9,158,805 13,918,384 13,940,782 
Lower of cost or market inventory valuation adjustment78,499 (119,775)136,305 
9,237,304 13,798,609 14,077,087 
Operating expenses (exclusive of depreciation and amortization)1,300,277 1,394,052 1,285,838 
Selling, general and administrative expenses (exclusive of depreciation and amortization)
313,600 354,236 290,424 
Depreciation and amortization520,912 509,925 437,324 
Goodwill and long-lived asset impairments545,293 152,712 — 
Total operating costs and expenses11,917,386 16,209,534 16,090,673 
Income (loss) from operations(733,743)1,277,044 1,623,993 
Other income (expense):
Earnings of equity method investments6,647 5,180 5,825 
Interest income7,633 22,139 16,892 
Interest expense(126,527)(143,321)(131,363)
Gain on business interruption insurance settlement81,000 — — 
Gain on sales-type leases33,834 — — 
Loss on early extinguishment of debt(25,915)— — 
Gain on foreign currency transactions2,201 5,449 6,197 
Other, net7,824 5,013 2,923 
(13,303)(105,540)(99,526)
Income (loss) before income taxes(747,046)1,171,504 1,524,467 
Income tax expense (benefit)(232,147)299,152 347,243 
Net income (loss)(514,899)872,352 1,177,224 
Less net income attributable to noncontrolling interest86,549 99,964 79,264 
Net income (loss) attributable to HollyFrontier stockholders$(601,448)$772,388 $1,097,960 
Earnings (loss) per share:
Basic$(3.72)$4.64 $6.25 
Diluted$(3.72)$4.61 $6.19 
Cash dividends declared per common share$1.40 $1.34 $1.32 
Average number of common shares outstanding:
Basic161,983 166,287 175,009 
Diluted161,983 167,385 176,661 

Other Financial Data
Years Ended December 31,
 202020192018
 (In thousands)
Net cash provided by operating activities$457,931 $1,548,611 $1,554,416 
Net cash used for investing activities$(330,162)$(972,914)$(360,520)
Net cash provided by (used for) financing activities$353,226 $(848,255)$(664,328)
Capital expenditures$330,160 $293,763 $311,029 
EBITDA (1)
$(193,789)$1,702,647 $1,996,998 

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(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 7A of Part II of this Form 10-K.

Supplemental Segment Operating Data
Our operations are organized into three reportable segments, Refining, Lubricants and Specialty Products and HEP. See Note 20 “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 and Woods Cross Refineries. The following tables set forth information, including non-GAAP performance measures, about our consolidated refinery operations, which has been retrospectively adjusted to reflect the revised regional groupings upon the Cheyenne Refinery permanently ceasing petroleum refining operations in the third quarter of 2020. 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 7A of Part II of this Form 10-K.
Years Ended December 31,
202020192018
Consolidated
Crude charge (BPD) (1)
365,190 388,860 384,380 
Refinery throughput (BPD) (2)
395,080 417,570 413,780 
Sales of produced refined products (BPD) (3)
391,670 414,370 408,390 
Refinery utilization (4)
90.2 %96.0 %94.9 %
Average per produced barrel (5)
Refinery gross margin$7.29 $15.92 $16.50 
Refinery operating expenses (6)
6.05 6.12 6.06 
Net operating margin$1.24 $9.80 $10.44 
Refinery operating expenses per throughput barrel (7)
$6.00 $6.07 $5.98 

(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 405,000 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 7A of Part II of this Form 10-K.
(6)Represents total Mid-Continent and West regions operating expenses, exclusive of long-lived asset impairment charges and depreciation and amortization, divided by sales volumes of refined products produced at our refineries.
(7)Represents total Mid-Continent and West regions operating expenses, exclusive of long-lived asset impairment charges and depreciation and amortization, divided by refinery throughput.

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Lubricants and Specialty Products Segment Operating Data

The following table sets forth information about our lubricants and specialty products operations and includes Red Giant Oil for the period August 1, 2018 (date of acquisition) through December 31, 2020, and Sonneborn for the period February 1, 2019 (date of acquisition) through December 31, 2020.
Years Ended December 31,
202020192018
Lubricants and Specialty Products
Throughput (BPD)19,645 20,251 19,590 
Sales of produced barrels sold (BPD)32,902 34,827 30,510 

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
(In thousands)
Year Ended December 31, 2020
Sales and other revenues$505,424 $1,667,809 $(370,023)$1,803,210 
Cost of products sold456,194 1,185,116 (370,023)1,271,287 
Operating expenses96,463 119,605 — 216,068 
Selling, general and administrative expenses22,276 135,540 — 157,816 
Depreciation and amortization29,071 51,585 — 80,656 
Goodwill and long-lived asset impairments (4)
167,017 119,558 — 286,575 
Income (loss) from operations$(265,597)$56,405 $— $(209,192)
Year Ended December 31, 2019