UNITED STATES
 SECURITIES AND EXCHANGE COMMISSION
 WASHINGTON, DC 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, 2023
 OR

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

 Commission File No. 001-36550
 ________________________________________________________________________________________________________________________
 PAR PACIFIC HOLDINGS, INC.
 (Exact name of registrant as specified in its charter)
 ________________________________________________________________________________________________________________________

 Delaware
 84-1060803

 (State or other jurisdiction of
 (I.R.S. Employer

 incorporation or organization)
 Identification No.)

 825 Town & Country Lane, Suite 1500

 Houston,
 Texas
 77024

 (Address of principal executive offices)
 (Zip Code)

 Registrant's telephone number, including area code: ( 281) 899-4800
 Securities registered under Section 12(b) of the Act:

 Title of each class
 Trading Symbol(s)
 Name of Exchange on which registered

 Common stock, $0.01 par value
 PARR
 New York Stock Exchange

 Securities registered pursuant to Section 12(g) of the Act: None

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

 Large accelerated filer

 Accelerated filer

 Non-accelerated filer

 Smaller reporting company

 Emerging growth company

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

 Indicate by check mark whether the registrant 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.
 If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements.
 Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant's executive officers during the relevant recovery period pursuant to §240.10D-1(b).
 Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes No

 The aggregate market value of voting and non-voting common equity held by non-affiliates of the registrant was approximately $ 1,550,243,970 based on the closing sales price of the common stock on the New York Stock Exchange on June 30, 2023. As of February 22, 2024, 59,575,453 shares of the registrant's Common Stock, $0.01 par value, were issued and outstanding.

 Documents Incorporated By Reference
 Certain information required to be disclosed in Part III of this report is incorporated by reference from the registrant's definitive proxy statement or an amendment to this report, which will be filed with the SEC not later than 120 days after the end of the fiscal year covered by this report.

 PAGE

 Item 1. BUSINESS

 Item 1A. RISK FACTORS

 Item 1B. UNRESOLVED STAFF COMMENTS

 Item 1C. CYBERSECURITY

 Item 2. PROPERTIES

 Item 3. LEGAL PROCEEDINGS

 Item 4. MINE SAFETY DISCLOSURES

 Item 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND ISSUER PURCHASES OF EQUITY SECURITIES

 Item 6. [RESERVED]

 Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 Item 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

 Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

 Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

 Item 9A. CONTROLS AND PROCEDURES

 Item 9B. OTHER INFORMATION

 Item 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTION

 Item 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE

 Item 11. EXECUTIVE COMPENSATION

 Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

 Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

 Item 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES

 Item 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

 Item 16. FORM 10-K SUMMARY
 F- 60

 i

 Glossary of Selected Industry Terms
 Unless otherwise noted or indicated by context, the following terms used in this Annual Report on Form 10- K have the following meanings:

 barrel or bbl

 A common unit of measure in the oil industry, which equates to 42 gallons.

 blendstocks

 Various compounds that are combined with gasoline or diesel from the crude oil refining process to make finished gasoline and diesel; these may include natural gasoline, FCC unit gasoline, ethanol, reformate, or butane, among others.

 Brent

 A light, sweet North Sea crude oil, characterized by an API gravity of 38 degrees and a sulfur content of approximately 0.4% by weight that is used as a benchmark for other crude oils.

 cardlock
 Automated unattended fueling sites that are open all day and are designed for commercial fleet vehicles.

 catalyst

 A substance that alters, accelerates, or instigates chemical changes, but is not produced as a product of the refining process.

 CO2

 Carbon dioxide.

 condensate

 Light hydrocarbons which are in gas form underground but are a liquid at normal temperatures and pressure.

 crack spread

 A simplified calculation that measures the difference between the price for refined products and crude oil. For example, we reference the 3-1-2 Singapore crack spread, which approximates the per barrel results from processing three barrels of Brent crude oil to produce one barrel of gasoline and two barrels of distillates (diesel and jet fuel).

 distillates

 Refers primarily to diesel, heating oil, kerosene, and jet fuel.

 ethanol

 A clear, colorless, flammable oxygenated liquid. Ethanol is typically produced chemically from ethylene or biologically from fermentation of various sugars from carbohydrates found in agricultural crops and cellulosic residues from crops or wood. It is used in the United States as a gasoline octane enhancer and oxygenate.

 feedstocks

 Crude oil or partially refined petroleum products that are further processed into refined products.

 HSFO
 High sulfur fuel oil.

 jobber

 A petroleum marketer.

 LPG
 Liquified petroleum gas.

 LSFO

 Low sulfur fuel oil.

 Mbbls

 Thousand barrels of crude oil or other liquid hydrocarbons.

 Mbpd

 Thousand barrels per day.

 MMbbls

 Million barrels of crude oil or other liquid hydrocarbons.

 MMbtu

 Million British thermal units, a unit of measurement for natural gas.

 MMcfd

 Million cubic feet per day, a unit of measurement for natural gas.

 MW

 Megawatt, a unit of measurement for electricity or other energy transfer. A watt is a unit of work at the rate of one joule per second or current at the rate of one ampere across a potential difference of one volt.

 NOx

 Nitrogen oxides.

 refined products

 Petroleum products, such as gasoline, diesel, and jet fuel, that are produced by a refinery.

 SO2

 Sulfur dioxide.

 SPM

 Single point mooring. Also known as a single buoy mooring, refers to a loading buoy that is anchored offshore and serves as an interconnect for tankers loading or offloading crude oil and refined products.

 throughput

 The volume processed through a unit or refinery.

 turnaround

 A periodically required standard procedure to inspect, refurbish, repair, and maintain a refinery. This process involves the shutdown and inspection of major processing units and typically occurs every three to seven years, depending on unit type.

 ULSD
 Ultra-low sulfur diesel.

 WTI

 West Texas Intermediate crude oil, a light, sweet crude oil, typically characterized by an API gravity between 38 degrees and 40 degrees and a sulfur content of approximately 0.3% by weight that is used as a benchmark for other crude oils.

 yield

 The percentage of refined products that is produced from crude oil and other feedstocks, net of fuel used as energy.

 ii

 Item 1. BUSINESS

 OVERVIEW
 Par Pacific Holdings, Inc., headquartered in Houston, Texas, is a growth-oriented energy company providing both renewable and conventional fuels to the western United States.
 Our business is organized into three primary segments:
 1) Refining - We own and operate four refineries with total operating crude oil throughput capacity of 219 Mbpd. Our refineries in Kapolei, Hawaii, Newcastle, Wyoming, Tacoma, Washington, and Billings, Montana, convert crude oil into gasoline, distillate, asphalt and other products to serve the state of Hawaii and areas ranging from Washington state to the Dakotas and Wyoming.
 2) Retail - We operate fuel retail outlets in Hawaii, Washington, and Idaho. We operate convenience stores and fuel retail sites under our "Hele" and "nomnom" brands, "76" branded fuel retail sites and other sites operated by third parties that sell gasoline, diesel, and retail merchandise such as soft drinks, prepared foods, and other sundries. We also operate unattended cardlock stations.
 3) Logistics - We operate an extensive multi-modal logistics network spanning the Pacific, the Northwest, and the Rocky Mountain regions. This network includes an SPM in Hawaii, a unit train-capable rail loading terminal in Washington, and other terminals, pipelines, trucking operations, marine vessels, storage facilities, loading and truck racks, and rail facilities for the movement of petroleum, refined products, and ethanol in and among the Hawaiian islands, between the U.S. West Coast, and the Rocky Mountain region.
 As of December 31, 2023, we owned a 46% equity investment in Laramie Energy, LLC ("Laramie Energy"), an entity focused on developing and producing natural gas in Garfield, Mesa, and Rio Blanco counties, Colorado. As of December 31, 2023, through the Billings Acquisition (as defined in Note 5—Acquisitions under Item 8 of this Annual Report on Form 10-K), we own a 65% and a 40% equity investment in Yellowstone Energy Limited Partnership ("YELP") and Yellowstone Pipeline Company ("YPLC"), respectively.
 Our Corporate and Other reportable segment primarily includes general and administrative costs. Please read Note 23—Segment Information to our consolidated financial statements under Item 8 of this Form 10-K for detailed information on our operating results by segment.

 Macroeconomic Factors Affecting Our Business
 U.S. and Global Inflationary Factors. Energy prices are, among other factors, indicators of inflation, and the U.S. Federal Reserve (the "Fed") has taken significant steps to curb inflation, and continued to increase interest rates in 2023, from near zero percent at the beginning of 2022 to a range of 5.25% to 5.5% in December 2023. These actions by the Fed acted to lower U.S. inflation rates, which have decreased 3.4% year over year as of the December inflation report released in January 2024. The U.S. retail price for regular-grade gasoline averaged $3.52 per gallon in 2023, following gasoline price highs of approximately $5.01 per gallon in the summer of 2022. This decline was due, in part, to lower crude oil prices in 2023 compared with 2022 and higher gasoline inventories in the second half of 2023.
 The COVID-19 Pandemic. Subsequent to the pandemic, and various preventive and mitigating measures taken in response, refined product demand has largely returned to 2019 levels. Despite global additions to refining capacity, the availability of refining capacity has not kept pace with demand, and global refinery utilization is above normal levels. Consequently, refining product margins have been consistently above pre-pandemic margins since the spring of 2022.
 Geopolitical Conflicts. Given the nature of our operations, including sourcing crude oil and feedstocks, geopolitical conflicts may affect our business and results of operations. The Russia-Ukraine war, the Israel-Palestine conflict, Houthi attacks in the Red Sea, and Iranian activities in the Strait of Hormuz have all disrupted global trade patterns, increased crude oil price volatility, and increased freight costs and delivery times.
 We continue to actively monitor the impact of these and other global situations on our people, operations, financial condition, liquidity, suppliers, customers, and industry, and are actively responding to the impacts that these matters have on our business. Please read "Item 1A. — Risk Factors" and "Item 7. — Management's Discussion and Analysis of Financial

 Condition and Results of Operations — Overview" for further discussion of the risks, uncertainties, and actions we have taken in response to the conditions noted above and the resulting economic impacts.
 Corporate Information
 Our common stock is listed and trades on the New York Stock Exchange (the "NYSE") under the ticker symbol "PARR." Our principal executive office is located at 825 Town & Country Lane, Suite 1500, Houston, Texas 77024 and our telephone number is (281) 899-4800. Throughout this Annual Report on Form 10-K, the terms "Par," the "Company," "we," "our," and "us" refer to Par Pacific Holdings, Inc. and its consolidated subsidiaries unless the context suggests otherwise.
 Available Information
 Our website address is www.parpacific.com. Information contained on our website is not part of this Annual Report on Form 10-K. Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any other materials filed with, or furnished to, the U.S. Securities and Exchange Commission ("SEC") by us are available on our website (under "Investors") free of charge, as soon as reasonably practicable after such reports are filed with, or furnished to, the SEC. Alternatively, you may access these reports at the SEC's website at www.sec.gov.

 OPERATING SEGMENTS

 We own and operate refineries in Hawaii, Wyoming, Washington, and Montana, with total operating crude oil throughput capacity of 219 Mbpd. During the year ended December 31, 2023, our refineries processed 170.3 Mbpd of crude oil and sold 183.1 Mbpd of refined products.
 Our refineries consist of various units, including crude oil distillation, vacuum distillation, hydrocracking, catalytic reforming, naphtha hydrotreating, diesel hydrotreating, fluidized catalytic cracking, alkylation, and isomerizing units. Our refineries process a variety of condensate and light and heavy crude oils purchased from domestic and foreign suppliers to produce LPG, naphtha, gasoline, jet fuel, ULSD, marine fuel, LSFO, HSFO, asphalt, and other associated refined products.
 Our refineries are connected with each other and with the communities we serve via pipelines, terminals, tankers, and other transportation mechanisms. These various forms of transportation allow the movement of crude oil, various feedstocks, and a variety of refined products from our suppliers to our refineries, among our refineries, and from our refineries to our customers. Please read our Logistics segment discussion below for additional information.
 Descriptions of our refineries and their capacities are below.
 Hawaii Refinery. Our Hawaii refinery is located in Kapolei, Hawaii, on the island of Oahu, and is rated at 94 Mbpd of Crude unit operating throughput capacity. The Hawaii refinery's major processing units produce LPG, naphtha, gasoline, jet fuel, ULSD, marine fuel, LSFO, HSFO, asphalt, and other associated refined products. We believe the configuration of our Hawaii refinery uniquely fits the demands of the Hawaii market. We believe the 3-1-2 Singapore Crack Spread is the most representative market indicator for our Hawaii operations. The 3-1-2 Singapore Crack Spread is computed by taking one barrel of gasoline and two barrels of distillates (diesel and jet fuel) from three barrels of Brent crude oil.
 Montana Refinery. Our Montana refinery is located along the Yellowstone River just outside Billings, Montana, and is rated at 63 Mbpd throughput capacity. The Montana refinery is a high-conversion, complex facility that processes low-cost Western Canadian and regional Rocky Mountain crude oil to produce gasoline, distillate, asphalt, and other products to serve the Rocky Mountain region. Our Montana refinery assets include a 65% interest in an adjacent co-generation facility. We believe the RVO Adjusted USGC 3-2-1 is the most representative market indicator for our operations in Billings, Montana. The RVO Adjusted USGC 3-2-1 Index is computed by taking three barrels of WTI crude oil and converting them into two barrels of USGC gasoline and one barrel of USGC ULSD, less 100% of the RVO cost.
 Washington Refinery. Our Washington refinery is located in Tacoma, Washington, and is rated at 42 Mbpd throughput capacity. The Washington refinery's major processing units produce ULSD, jet fuel, gasoline, asphalt, and other associated refined products that are primarily marketed in the Pacific Northwest. We believe the RVO Adjusted Pacific Northwest 3-1-1-1 Index is the most representative market indicator for our operations in Tacoma, Washington with improved historical correlations to our reported adjusted gross margin compared to prior reported indices. The RVO Adjusted Pacific Northwest 3-1-1-1 Index is computed by taking one part gasoline (PNW sub-octane), one part distillate (PNW ULSD), and one part VGO (USGC VGO) as created from three barrels of WTI Crude, less 100% of the RVO cost for gasoline and distillate. In

 January 2024, our Washington refinery was awarded the U.S. Environmental Protection Agency's ("EPA") ENERGY STAR certification, indicating the refinery performs in the top 25% of similar facilities nationwide for energy efficiency and meets strict energy efficiency performance levels set by the EPA.
 Wyoming Refinery. Our Wyoming refinery is located in Newcastle, Wyoming, and is rated at 20 Mbpd throughput capacity. The Wyoming refinery's major processing units produce gasoline, ULSD, jet fuel, and other associated refined products. We believe the RVO Adjusted USGC 3-2-1 the most representative market indicator for our Wyoming refining and fuel distribution operations with improved historical correlations to our reported adjusted gross margin compared to prior reported indices. Please read the discussion of the RVO Adjusted USGC 3-2-1 Index in the Montana refinery section above for further information. In January 2024, our Wyoming refinery was also awarded the EPA's ENERGY STAR certification.
 Crude Oil Supply
 We source our crude oil feedstock from North America, Asia, Latin America, Africa, the Middle East, and other sources. Effective March 3, 2022, we suspended purchases of Russian crude oil as a response to the Russia-Ukraine conflict.
 Competition
 All facets of the energy industry are highly competitive. Our competitors include major integrated, national, and independent energy companies. Many of these competitors have greater financial and technical resources and staff which may allow them to better withstand and react to changing and adverse market conditions. In addition, the energy industry is subject to global economic and political factors and changing governmental regulations. Our operating results are affected by changes in pricing for crude oil, feedstocks, and natural gas, as well as changes in the markets that we serve. All our refineries' product slates are tailored to meet local demand. In the continental U.S., our refined products typically serve areas ranging from Washington state to the Dakotas and Wyoming.
 Our refining business sources and obtains all of our crude oil from third-party sources and competes globally for crude oil and feedstocks.

 The retail segment includes locations in Hawaii, Washington, and Idaho where we set the price to the retail consumer. Certain of our Hawaii locations and all of the Washington and Idaho locations are operated by our personnel and include various sizes of convenience stores, snack shops, and kiosks. The remaining locations in Hawaii are cardlocks or sites operated by third parties where we retain ownership of the fuel and set retail pricing.
 As of December 31, 2023, our company-operated convenience stores with fuel in Hawaii are branded "Hele," our proprietary brand. Additionally, some of our partner sites operate under our proprietary Hele fuel brand. We also hold exclusive licenses within the state of Hawaii to utilize the "76" brand for retail locations. The "76" license agreement expires October 31, 2031, unless extended by mutual agreement. Since its launch in 2016, the Hele brand has won several awards for being the preferred fuel choice for Hawaii customers. Our cardlock locations on Kauai are branded Kauai Automated Fuels ("KAF").
 We operate convenience stores at all of our retail fuel outlets in Washington and Idaho. We use our proprietary "nomnom" brand at both the fueling facilities and stores. Our current store count includes the acquisition and rebranding of three convenience store locations in Washington acquired on December 2, 2022. Additionally, we opened a new to industry site in a growth area of Spokane, Washington, on September 25, 2023.
 Competition
 Competitive factors that affect our retail performance include product price, station appearance, location, customer service, and brand awareness. Our Hawaii competitors include the Shell, Texaco, Costco, Safeway, and Sam's Club national brands, regional brand Aloha, and other local retailers. Competitors of our Pacific Northwest retail assets include the Chevron, Exxon, Conoco, Safeway, and Costco national brands, regional brands such as Maverik, Holiday, and Fred Meyer, and other local retail brands.

 Our logistics segment generates revenues by charging fees for transporting crude oil to our refineries, delivering refined products to wholesale and bulk customers and to our retail business, and storing crude oil and refined products. Substantially all of our revenues from our logistics segment represent intercompany transactions that are eliminated in consolidation.

 Hawaii Logistics
 Our logistics network extends throughout the State of Hawaii. On Oahu, the system begins with our SPM located 1.7 miles offshore of our Hawaii refinery. This SPM allows for the safe, reliable, and efficient receipt of crude oil shipments to the Hawaii refinery, as well as both the receipt and export of finished products. Connecting the SPM to the Hawaii refinery are three undersea pipelines, two for the import or export of refined products and one for crude oil. We also have an on-shore pipeline manifold which allows for crude oil to be transferred between the Hawaii refinery and the IES Downstream, LLC ("IES") storage facility located approximately 2 miles away. From the Hawaii refinery, we distribute refined products through our logistics network of pipelines, trucks, leased barges, terminals, and storage facilities throughout the islands of Oahu, Maui, Hawaii, Molokai, and Kauai and for export to the U.S. West Coast and Asia.
 Montana Logistics
 On June 1, 2023, we purchased distribution and logistics assets in the upper Rockies region, including the wholly owned Silvertip Pipeline, a 40% interest in the Yellowstone refined products pipeline, and four wholly owned and three joint venture refined product terminals located in Montana and Washington. Our Montana logistics network services the PADD IV and V regions.
 Washington Logistics
 Our Washington logistics network includes storage capacity, a proprietary jet fuel pipeline that serves Joint Base Lewis McChord, a marine terminal with waterfront property, a unit train-capable rail loading terminal, a manifest rail siding, including asphalt, butane, biodiesel loading and unloading facilities, and a truck rack. These assets provide connectivity to Bakken, Canadian, and Alaskan crude oil, renewable fuels, and the Pacific, West Coast, Pacific Northwest, and Rockies product markets.
 Wyoming Logistics
 Our Wyoming logistics network includes crude storage tanks and a crude oil pipeline that provides us access to crude oil from the Powder River Basin. This network also includes a refined products pipeline that transports product from our Wyoming refinery to a common carrier with access to Rapid City, South Dakota.
 The logistics network in Wyoming includes crude oil and refined product storage capacity, loading racks, and a rail siding at the refinery site. We also own and operate a jet fuel storage facility and pipeline that serve Ellsworth Air Force Base in South Dakota.

 Markets
 Hawaii Market
 Hawaii's visitor industry is the primary driver of the state's economy. In August 2023, the Maui wildfires dominated news headlines and the tragic event had a significant impact in Maui County. According to data from Hawaii's State Department of Business, Economic Development and Tourism ("DBEDT"), between August and October 2023, visitor arrivals by air to Maui County decreased 51.4 percent compared to the same period in 2022.
 The University of Hawaii Economic Organization ("UHERO"), however, noted that the Maui visitor industry is recovering faster than anticipated and visitors to the rest of the state have reached record levels. Per DBEDT, 9.6 million visitors arrived in Hawaii in 2023, a 4% increase from 9.2 million in 2022. Total arrivals declined 7% when compared to 10.4 million visitors in pre-pandemic 2019. Most of these visitors were domestic travelers; the Japanese market recovery is slower due to the relative weakness of the yen to the U.S. Dollar. This leaves Hawaii's dependence on the U.S. market unusually high. The total number of visitors to Hawaii is expected to be essentially flat in 2024 with an expected return to moderate growth in 2025. In 2023, overall total visitor spending rose to $20.8 billion, compared to $19.7 billion in 2022 and $17.7 billion in 2019.
 Overall, UHERO expects Hawaii's job growth to be about 1% in 2024. According to DBEDT, the state unemployment rate is expected to be 3.0% in 2023, and will improve to 2.8% in 2024, 2.6% in 2025, and 2.4% in 2026. As measured by the Honolulu Consumer Price Index for Urban Consumers, inflation is expected to be 2.8% in 2023, lower than the projected U.S. consumer inflation rate of 4.1% for 2023. Hawaii consumer inflation is expected to decrease to 2.2% by 2026.

 Mainland Markets
 Spokane, Washington, and Northwest Idaho are the primary regions of our Pacific Northwest retail operations and are enjoying significantly higher population growth rates than the country as a whole. The U.S. Census Bureau noted that the population increased 14.6% in Washington and 17.3% in Idaho from 2010 to 2020 versus a national increase of only 7.4%. Spokane is a regional hub in eastern Washington, with a population of over a half million and a variety of employers in health care, retail, and other industries. According to the Spokane City Department of Economic Development, the unemployment rate was 3.4% through September 2023, and the average annual wage was $62 thousand in the first quarter of 2023 in positions covered by unemployment insurance.
 A significant portion of the products produced by our Washington refinery stay within the Puget Sound region. Washington is one of the fastest growing states in the nation, and most of this growth is occurring in the Puget Sound area due to large technology and information industry companies. According to the U.S. Bureau of Economic Analysis (the "BEA"), gross domestic product ("GDP") for the State of Washington grew by 5.4% from 2022 to 2023 based on seasonally adjusted preliminary third quarter 2023 data.
 The primary market for our Wyoming refined products is the Black Hills Region in South Dakota, driven largely by Pennington, Lawrence, and Meade counties, which represents nearly half of the state's taxable tourism sales. According to the U.S. Census Bureau, the population in Pennington County, the state's second largest county, increased by 8.2% from 2010 to 2020 compared to 7.4% nationally over the same period. Demand for gasoline is highly seasonal, with a large increase in demand during the summer driving season. The South Dakota economy is anchored by tourism, including visitors to Mount Rushmore and the Black Hills, as well as government and health care spending. According to the South Dakota Department of Tourism, visitor spending has increased in 2023, above pre-pandemic levels. South Dakota welcomed 14.7 million visitors for the year, resulting in visitor spending of approximately $5.0 billion in 2023, an increase of 4.9% compared to 2022 and 22% over the pre-pandemic spending heights reached in 2019. Additionally, $1.1 billion, or 22%, of tourism dollars were spent on transportation services, representing an increase of nearly 17% over pre-pandemic transportation spending.
 A significant portion of the products produced by our Montana refinery serve a robust economy that includes the states of Montana, Wyoming, Colorado, Idaho, Utah, eastern Washington, and the Dakotas. The business is operated as an integrated fuels value chain, deriving value along the entire chain from the sourcing of crude oil to refining, distributing, and marketing of fuels to our customers. The Montana refinery complements the markets served by our Washington and Wyoming refineries by benefiting from the growth of the Pacific Northwest and strong seasonal demand in the Rockies and surrounding areas.
 In addition to supplying the Rocky Mountain and Pacific Northwest markets with transportation fuels, our Montana refinery also supplies asphalt to customers throughout the United States, giving the refinery a strategic advantage in its ability to process heavy, sour crude oils. Our crude processing flexibility allows us to maintain a diverse product offering, including jet fuel, gasoline, diesel and asphalt, through a robust network of both proprietary and third-party terminals. This, along with the ability to deliver product via various transportation modes (e.g. pipeline, truck, rail), enables convenient supply options for our customers.

 OTHER OPERATIONS

 Laramie Energy
 As of December 31, 2023, we owned a 46% equity investment in Laramie Energy, an entity focused on developing and producing natural gas in Garfield, Mesa, and Rio Blanco counties, Colorado. As of June 30, 2020, we discontinued the application of the equity method of accounting for our investment in Laramie Energy because the book value of such investment had been reduced to zero. Effective February 21, 2023, we resumed the application of the equity method of accounting with respect to our investment in Laramie Energy. The balance of our investment in Laramie Energy was $14.3 million as of December 31, 2023. Please read Note 4—Investment in Laramie Energy to our consolidated financial statements under Item 8 of this Form 10-K for further information.
 Other Investments
 As noted in the Refining and Logistics discussions above, as of December 31, 2023 through the Billings Acquisition, we own a 65% and a 40% equity investment in YELP and YPLC, respectively. Please read Note 3—Refining and Logistics Equity Investments to our consolidated financial statements under Item 8 of this Form 10-K for further information.

 ENVIRONMENTAL REGULATIONS
 General
 Our activities are subject to existing federal, state, and local laws and regulations governing environmental quality and pollution control. Although no assurances can be made, we believe that, absent the occurrence of an extraordinary event, compliance with existing federal, state, and local laws, regulations, and rules regulating the release of materials in the environment or otherwise relating to the protection of human health, safety, and the environment will not have a material effect upon our capital expenditures, earnings, or competitive position with respect to our existing assets and operations. We cannot predict what effect additional regulation or legislation, enforcement policies, and claims for damages to property, employees, other persons, and the environment resulting from our operations could have on our activities.
 Periodically, we receive communications from various federal, state, and local governmental authorities asserting violations of environmental laws and/or regulations. These governmental entities may also propose or assess fines or require corrective actions for these asserted violations. We intend to respond in a timely manner to all such communications and to take appropriate corrective action. Except as disclosed below, we do not anticipate that any such matters currently asserted will have a material impact on our financial condition, results of operations, or cash flows.
 Refining activities
 Like other petroleum refiners, our operations are subject to extensive and evolving federal and state environmental regulations governing air emissions, wastewater discharges, and solid and hazardous waste management activities. Many of these regulations are becoming increasingly stringent, and the cost of compliance can be expected to increase over time. Our policy is to accrue environmental and clean-up related costs of a non-capital nature when it is probable that a liability has been incurred and the amount can be reasonably estimated. Such estimates may be subject to revision in the future as regulations and other conditions change.
 Climate Change and Regulation of Greenhouse Gases
 According to many scientific studies, emissions of CO2, methane, NOX, and other gases commonly known as greenhouse gases ("GHGs") are contributing to global warming of the earth's atmosphere and to global climate change. In response to the scientific studies, legislative and regulatory initiatives have been underway to limit GHG emissions. The U.S. Supreme Court determined that GHG emissions fall within the federal Clean Air Act ("CAA") definition of an "air pollutant." In response, the U.S. Environmental Protection Agency ("EPA") promulgated an endangerment finding, paving the way for regulation of GHG emissions under the CAA. The EPA has now begun regulating GHG under the CAA. New construction or material expansions that meet certain GHG emissions thresholds will likely require that, among other things, a GHG permit be issued in accordance with the federal CAA regulations, and we will be required, in connection with such permitting, to undertake a technology review to determine appropriate controls to be implemented with the project in order to reduce GHG emissions. Based on current company operations, however, our existing refining activities are not subject to current federal GHG permitting requirements.
 The EPA has also promulgated rules requiring large sources to report their GHG emissions. Reports are being made in connection with our refining business. Sources subject to these reporting requirements also include on and offshore petroleum and natural gas production and onshore natural gas processing and distribution facilities that emit 25,000 metric tons or more of CO2 equivalent per year in aggregate emissions from all site sources.
 In 2007, the State of Hawaii passed Act 234, which required that GHG emissions be rolled back on a statewide basis to 1990 levels by the year 2020. In June of 2014, the Hawaii Department of Health ("DOH") adopted regulations that require each major facility to reduce CO2 emissions by 16% by 2020 relative to a calendar year 2010 baseline (the first year in which GHG emissions were reported to the EPA under 40 CFR Part 98). The GHG rules include an alternative for facilities to demonstrate that further GHG reductions are not economically viable and an additional provision that authorized the DOH to issue a waiver if GHGs are being effectively controlled as a consequence of other state initiatives and regulations such as the Renewable Portfolio Standard. The Hawaii GHG regulation allows for "partnering" with other facilities that have or are expected to make more significant CO2/GHG reductions. Accordingly, our Par East and Par West Hawaii refineries submitted a GHG reduction plan and a permit application that incorporated the partnering provisions. The DOH issued a GHG permit, which caps GHG emissions from both refineries at 904,945 metric tons per year which (as required by regulation) is 16% below the combined facility GHG emission levels of 2010. Since ceasing refining operations at the Par West facility in 2020, our annual emissions are well below the GHG emissions cap.

 The State of Washington and its political subdivisions passed several climate-focused laws in 2021 that are relevant to our operations within the state. These include a low-carbon fuel standard ("LCFS") designed to reduce the carbon intensity of transportation fuels by twenty percent by 2038 and a "cap and trade"-style program for GHG emissions covering industrial facilities and transportation fuels starting in 2023. The Washington Department of Ecology ("WDOE") issued final rules implementing the LCFS effective on January 1, 2023, implementing requirements that are now in effect and will gradually reduce the carbon intensity of fuels sold in the state over time by annually lowering that limit. The WDOE has also issued final rules with respect to the "cap and trade"-style program with an effective date of November 1, 2022, with credit allocations and auctions commencing during 2023. While these programs are not expected to result in a material impact to earnings in the immediate term, both programs involve gradual tightening of standards over time and will likely require us to take additional actions or credit purchases, some of which may eventually be material. Both programs are likely to reduce transportation fuel demand. In addition to action by the State, on November 16, 2021, the Tacoma City Council adopted its Tideflats and Industrial Land Use Regulations, which prohibits new petroleum storage and allows for only limited additions of clean fuel infrastructure.
 Additional regulatory, legislative, and judicial developments are likely to occur in the future. The Administration's return to the Paris Climate Accord, actions voiding the prior Administration's orders on the social cost of carbon, and efforts to develop a "whole of government" strategy to aggressively address climate change issues suggest the imminence of such changes. Such developments may affect how these GHG initiatives will impact us. They may also impact the use of and demand for petroleum products, which could impact our business. Further, apart from these developments, tort claims alleging property damage against GHG emissions sources may be asserted. Due to the uncertainties surrounding the regulation of and other risks associated with GHG emissions, we cannot predict the financial impact of related developments on us.
 National Ambient Air Quality Standards
 The EPA has adopted a number of more stringent National Ambient Air Quality Standards ("NAAQS"). States are required to develop State Implementation Plans and ultimately local air districts are required to adopt rules designed to improve air quality over time. More stringent air pollutant standards and corresponding rules have already impacted and will continue to cause many refineries to invest heavily in additional air pollution controls. Thus far, Hawaii air quality, particularly on Oahu where our Hawaii refinery is located, has met even the most recent NAAQS, and the Hawaii refinery has not been required to install new controls as result of local rules. Even so, NAAQS could and, to a degree, have already forced some changes for our customer base. Power plants on the Big Island, where SO2 levels are already elevated due to volcanic activity, are switching from LSFO to diesel fuel. On Oahu, the state's largest utility frequently cites compliance with NAAQS as one of its justifications for moving towards a cleaner bridge fuel before reaching its renewable goals. On October 1, 2015, the EPA adopted rules, which were reaffirmed in December 2020, that substantially tightened the NAAQS for ground-level ozone. These rules are causing many areas of the country to develop requirements for additional controls and limits on combustion emissions and emissions of volatile organic compounds. In October 2021, the EPA announced its intent to revisit the December 2020 decision retaining the 2015 NAAQS standard, opening the door to potential additional tightening of those standards and additional requirements for states around the country to adopt more stringent controls, but no action has been taken in that respect to date. On February 7, 2024, EPA lowered the fine particulate NAAQS standards. We do not currently anticipate that the NAAQS standards will materially impact our operations, but the new standards could materially impact future projects, particularly at our refineries in Montana and Washington.
 Fuel Standards
 In 2007, the U.S. Congress passed the Energy Independence and Security Act ("EISA") which, among other things, set a target fuel economy standard of 35 miles per gallon for the combined fleet of cars and light trucks in the U.S. by model year 2020 and contained an expanded Renewable Fuel Standard (the "RFS"). In August 2012, the EPA and National Highway Traffic Safety Administration ("NHTSA") jointly adopted regulations that establish vehicle carbon dioxide emissions standards and an average industry fuel economy of 54.5 miles per gallon by model year 2025. On March 31, 2022, the EPA and NHTSA published a final rule containing additional fuel efficiency standards for cars and light trucks that include 8-10% reductions of GHG emissions annually through model year 2026. On July 28, 2023, NHTSA issued a notice of proposed rule making for cars and light trucks for model years 2027-2032. By model year 2032, the revised standards would require an industry-wide fleet average of 58 miles per gallon for passenger cars and light-duty trucks. Higher fuel economy standards have the potential to reduce demand for our refined transportation fuel products.
 Under EISA, the RFS requires an increasing amount of renewable fuel to be blended into the nation's transportation fuel supply. Over time, higher annual RFS requirements have the potential to reduce demand for our refined transportation fuel products. In the near term, the RFS will be satisfied primarily with fuel ethanol blended into gasoline. We, and other refiners subject to the RFS, may meet the RFS requirements by blending the necessary volumes of renewable fuels produced by us or purchased from third parties. To the extent that refiners will not or cannot blend renewable fuels into the products they produce

 in the quantities required to satisfy their obligations under the RFS program, those refiners must purchase renewable credits, referred to as Renewable Identification Numbers ("RINs"), to maintain compliance. To the extent that we exceed the minimum volumetric requirements for blending of renewable fuels, we can retain these RINs for current or future RFS compliance or sell those on the open market.
 Additionally, the RFS enables the EPA to exempt certain small refineries from the renewable fuels blending requirements in the event such requirements would cause disproportionate economic hardship to that refinery. In prior years, we have petitioned the EPA for a small refinery waiver for certain of our refineries. However, in 2022, EPA generally denied all small refinery exemption petitions, including ours. Litigation surrounding the 2022 RFS volumetric requirements and other aspects of those final rules, including the EPA's denial of small refinery relief, is ongoing in Wynnewood Ref. Co., LLC v EPA.
 The RFS may present production and logistics challenges for both the renewable fuels and the petroleum refining and marketing industries in that we may have to enter into arrangements to purchase RINs with other parties or purchase cellulosic biofuels RINs ("D3") waivers from the EPA to meet our obligations to use advanced biofuels, including biomass-based diesel and cellulosic biofuel, with potentially uncertain supplies of these new fuels.
 In October 2010, the EPA issued a partial waiver decision under the federal CAA to allow for an increase in the amount of ethanol permitted to be blended into gasoline from 10% ("E10") to 15% ("E15") for 2007 and newer light duty motor vehicles. In 2019, the EPA approved year-round sales of E15 but that approval has been overturned by the courts and, as of January 10, 2022, the Supreme Court has declined to review further appeals on that subject. On July 2, 2021, a three-judge panel of the U.S. Court of Appeals for the District of Columbia Circuit vacated the EPA's approval of year-round E15 sales. However, in response to supply challenges caused in part by Russia's invasion of Ukraine, the EPA has issued certain emergency waivers to permit additional E15 sales. There are numerous issues, including state and federal regulatory issues, that need to be addressed before E15 can be marketed on a large scale for use in traditional gasoline engines; however, increased renewable fuel in the nation's transportation fuel supply could reduce demand for our refined products.
 In March 2014, the EPA published a final Tier 3 gasoline standard that requires, among other things, that gasoline contain no more than 10 parts per million ("ppm") sulfur on an annual average basis and no more than 80 ppm sulfur on a per-gallon basis. The standard also lowered the allowable benzene, aromatics, and olefins content of gasoline. All our refineries are Tier 3 compliant.
 In addition to federal requirements, several states, including Washington, have proposed or enacted low carbon fuel standards applicable to transportation fuels. The Washington LCFS creates a carbon intensity score for transportation fuels and require fuel producers and importers who fall short of increasingly stringent annual carbon intensity goals to purchase credits.
 There will be compliance costs and uncertainties regarding how we will comply with the various requirements contained in the EISA, RFS, and other fuel-related regulations. We may experience a decrease in demand for refined petroleum products due to an increase in combined fleet mileage or due to refined petroleum products being replaced by renewable fuels.
 Solid and Hazardous Waste
 Several of our businesses generate wastes, including hazardous wastes, that are subject to regulation under the federal Resource Conservation and Recovery Act ("RCRA") and state statutes. The EPA has limited the disposal options for certain hazardous wastes and state regulation of the handling and disposal of certain wastes associated with refining operations is becoming more stringent. We believe that our operations are in material compliance with all applicable RCRA regulations.
 Superfund
 The Comprehensive Environmental Response, Compensation, and Liability Act ("CERCLA"), also known as the "Superfund" law, imposes liability, without regard to fault or the legality of the original conduct, on certain persons with respect to the release or threatened release of a "hazardous substance" into the environment. These persons include the current owner and operator of a site, any former owner or operator who operated the site at the time of a release, transporters, and persons that disposed or arranged for the disposal of hazardous substances at a site. CERCLA also authorizes the EPA and, in some cases, third parties to take actions in response to threats to the public health or the environment and to seek to recover from the responsible persons the costs of such action. State statutes impose similar liability.
 Under CERCLA, the term "hazardous substance" does not include "petroleum, including crude oil or any fraction thereof," unless specifically listed or designated. While this "petroleum exclusion" lessens the significance of our operations, we may generate wastes that may fall within CERCLA's definition of a "hazardous substance" in the course of our ordinary refining operations. Although we and, to our knowledge, our predecessors have used operating and disposal practices that were

 standard in the industry at the time, "hazardous substances" may have been disposed or released on, under, or from the properties currently or historically owned or leased by us or on, under, or from other locations where these wastes have been taken for disposal. At this time, we do not believe that we have any material liability associated with any Superfund site and we have not been notified of any claim, liability, or damages under CERCLA.
 Oil Pollution Act
 The Oil Pollution Act of 1990 ("OPA") and regulations thereunder impose a variety of requirements on "responsible parties" related to the prevention of crude oil spills and liability for damages resulting from such spills in U.S. waters. A "responsible party" includes the owner or operator of a facility or vessel or the lessee or permittee of the area in which an offshore facility is located. While liability limits apply in some circumstances, few defenses exist to the liability imposed by the OPA. We are not aware of the occurrence of any action or event that would subject us to liability under OPA and we believe that compliance with OPA's financial responsibility and other operating requirements will not have a material adverse effect on us.
 Discharges and Marine Protection
 The Clean Water Act ("CWA") regulates the discharge of pollutants to waters of the U.S., including wetlands, and requires a permit for the discharge of pollutants, including petroleum, to such waters. Certain facilities that store or otherwise handle crude oil are required to prepare and implement Spill Prevention, Control, and Countermeasure and Facility Response Plans relating to the possible discharge of oil to surface waters. We are required to prepare and comply with such plans and to obtain and comply with discharge permits. The CWA also prohibits spills of oil and hazardous substances to waters of the U.S. in excess of levels set by regulations and imposes liability in the event of a spill. We believe we are in substantial compliance with these requirements and that any noncompliance would not have a material adverse effect on us.
 Other statutes provide protection to animal and plant species. These laws and regulations may require the acquisition of a permit or other authorization before drilling or construction related to the oil and gas industry commences and may limit or prohibit construction, drilling, and other activities on certain lands lying within wilderness or wetlands and other protected areas and impose substantial liabilities for pollution resulting from our operations. For example, the Magnuson amendment to the Marine Mammal Protection Act may limit or restrict certain new oil terminals and oil-by-rail infrastructure in the state of Washington.
 State laws further regulate discharges of pollutants to surface and groundwaters, require permits that set limits on discharges to such waters, and provide civil and criminal penalties and liabilities for spills to both surface and groundwaters. Some states have imposed regulatory requirements to respond to concerns related to potential for groundwater impact from oil and gas exploration and production. For example, the Colorado Oil and Gas Conservation Commission ("COGCC") approved rules that require sampling of groundwater for hydrocarbons and other indicator compounds both before and after drilling.
 Air Emissions
 Our refining operations are subject to local, state, and federal regulations for the control of emissions from sources of air pollution. Administrative enforcement actions for failure to comply strictly with air regulations or permits may be resolved by payment of monetary fines and correction of any identified deficiencies. Alternatively, regulatory agencies could impose civil and criminal liability for non-compliance. An agency could require us to forgo construction or operation of certain air emission sources. We believe that we are in substantial compliance with air pollution control requirements.
 Our refining business is subject to very significant state and federal air permitting and pollution control requirements, including some that are the subject of ongoing enforcement activities by the EPA as described in more detail below. The EPA continues to review and, in many cases, tighten ambient air quality standards, which standards, along with the advancement of pollution control technologies, could result in new regulatory and permit requirements that will impact our refining activities and involve additional costs.
 On September 29, 2015, the EPA announced a final rule updating standards that control toxic air emissions from petroleum refineries, addressing, among other things, flaring operations, fence line air quality monitoring, and additional emission reductions from storage tanks and delayed coking units. Compliance with this rule has not had a material impact on our financial condition, results of operations, or cash flows to date. However, new operating and other regulatory standards could involve additional costs, and failure to comply with such standards could involve penalties, each of which could be material.

 Hawaii Consent Decree
 On July 18, 2016, Par Hawaii Refining, LLC ("PHR") and subsidiaries of Tesoro Corporation ("Tesoro") entered into a consent decree with the EPA, the U.S. Department of Justice and other state governmental authorities concerning alleged violations of the federal Clean Air Act related to the ownership and operation of multiple facilities owned or formerly owned by Tesoro and its affiliates ("Consent Decree"), including our refinery in Kapolei, Hawaii, that we acquired from Tesoro in 2013. On September 29, 2023, we received a letter from EPA related to the alleged violation of certain air emissions limits, controls, monitoring, and repair requirements under the Consent Decree. We are unable to predict the cost to resolve these alleged violations, but resolution will likely involve financial penalties or impose capital expenditure requirements that could be material. For more information, please read Note 18—Commitments and Contingencies to our consolidated financial statements under Item 8 of this Form 10-K.
 Coastal Coordination
 There are various federal and state programs that regulate the conservation and development of coastal resources. The federal Coastal Zone Management Act ("CZMA") was passed to preserve and, where possible, restore the natural resources of the coastal zone of the U.S. The CZMA provides for federal grants for state management programs that regulate land use, water use, and coastal development.
 Other Government Regulation
 OSHA
 We are subject to the requirements of the federal Occupational Safety and Health Act ("OSHA") and comparable state statutes. The OSHA hazard communication standard, the EPA community right-to-know regulations under Title III of the federal Superfund Amendments and Reauthorization Act, and similar state statutes require us to organize and/or disclose information about hazardous materials used or produced in our operations. Certain of this information must be provided to employees, state and local governmental authorities, and local citizens.

 SIGNIFICANT CUSTOMERS
 We sell a variety of refined products to a diverse customer base. The majority of our refined products are primarily sold through short-term contracts or on the spot market. For each of the years ended December 31, 2023, 2022, and 2021, we had one customer in our refining segment that accounted for 13%, 17%, and 13%, respectively, of our consolidated revenue. No other customer accounted for more than 10% of our consolidated revenues during the years ended December 31, 2023, 2022, and 2021.

 HUMAN CAPITAL
 Workforce Composition
 We believe our employees are our most valuable asset. By investing in our employees, we are able to achieve success and continue to execute on our mission and vision. At December 31, 2023, our workforce consisted of 1,814 employees, including 331 employees, or 18% of our total workforce, at our Hawaii, Washington, and Montana refineries represented by the United Steelworkers Union ("USW") with collective bargaining agreements effective through January 31, 2026. We also employ three employees in Montana in our Rocky Mountain Pipeline & Terminals business that are represented by the Rocky Mountain Union ("RMU") with an agreement effective through October 1, 2025. We value our employees and constantly strive to maintain and improve satisfactory relationships with them. Our 1,814 employees work in the following operating segments throughout the United States:

 Operating Segment

 Number of Employees

 Refining and Logistics

 1,064

 Corporate

 Total

 1,814

 Diversity and Inclusion
 Par is focused on recruiting and developing a diverse workforce. We prioritize outreach activities that increase the diversity of applicants for open positions and actively ensure that all open positions are posted on job boards that target female, minority, disabled, and military veteran candidates. We work to develop relationships with local organizations that provide services to historically underserved populations and make them aware of career opportunities at Par. As of December 31, 2023, our workforce consisted of 39% minorities, 32% women, 6% protected veterans, and 4% employees with disabilities.
 Par is committed to maintaining a safe, respectful, and inclusive workplace. A work environment that values all employees and their contributions is critical to our success in that it enables each employee to bring their unique perspectives to work each day. By embracing our differences and viewing diversity and inclusion as assets, we are able to realize our full and creative potential. We actively train our management on why diversity and inclusion are critical in the workplace, enabling them to demonstrate allyship and embrace the differences of others, whether cultural or simply diversity of thought. Par is proud to foster an environment where all employees feel safe, heard, and valued and where there is a commitment to creating a greater representation of opinions, backgrounds, and experiences.
 Culture and Values
 Par is a values-driven company. Our tight-knit community values integrity, creativity, hard work, and respect for others. These four pillars support our successes and strengthen our ability to be an effective and fun place to work. We value innovative thought and rally behind ideas that create new opportunities. We believe this drives our growth and success. We value the unique heritage, experiences, and contributions of everyone we get to work with and serve. Our commitment to doing the right thing with the highest ethical standards enables us to achieve our best results. As we pursue growth and success, we believe it is important to keep our people safe, to value our diversity, and to protect our environment.
 Benefits
 We offer highly competitive compensation, benefit, and time-off packages to promote employee fulfillment and work-life balance. Our benefits include our retirement savings plan with company match, employee stock purchase plan, extensive health and wellness benefits, generous time off allowance, and a tuition reimbursement program.
 Health and Safety
 Safety is paramount to every operation and activity we undertake at Par. We recognize that our responsible stewardship impacts every employee, every contractor, and every member of the community, and we embrace that responsibility. We promote a culture of continuous safety improvement with a keen eye for evaluating and managing risk. We continually monitor and improve the effectiveness of our health and safety programs, policies, and procedures to achieve this objective.

 CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS
 Certain statements in this Annual Report on Form 10-K may constitute "forward-looking" statements as defined in Section 27A of the Securities Act of 1933, as amended (the "Securities Act"), Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), the Private Securities Litigation Reform Act of 1995 ("PSLRA"), or in releases made by the SEC, all as may be amended from time to time. Such forward-looking statements involve known and unknown risks, uncertainties, and other important factors that could cause our actual results, performance, or achievements to differ materially from any future results, performance, or achievements expressed or implied by such forward-looking statements. Statements that are not historical fact are forward-looking statements. Forward-looking statements can be identified by, among other things, the use of forward-looking language, such as the words "plan," "believe," "expect," "anticipate," "intend," "estimate," "project," "may," "will," "would," "could," "should," "seeks," or "scheduled to," or other similar words or the negative of these terms or other variations of these terms or comparable language or by discussion of strategy or intentions. These cautionary statements are being made pursuant to the Securities Act, the Exchange Act, and the PSLRA with the intention of obtaining the benefits of the "safe harbor" provisions of such laws.
 The forward-looking statements contained in this Annual Report on Form 10-K are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. In addition, management's assumptions about future events may prove to be inaccurate. All readers are cautioned that the forward-

 looking statements contained in this Annual Report on Form 10-K are not guarantees of future performance and we cannot assure any reader that such statements will be realized or that the forward-looking events and circumstances will occur. Actual results may differ materially from those anticipated or implied in the forward-looking statements due to factors described in "Item 1A. — Risk Factors", "Item 7. — Management's Discussion and Analysis of Financial Condition and Results of Operations," and elsewhere in this Annual Report on Form 10-K. All forward-looking statements speak only as of the date they are made. We do not intend to update or revise any forward-looking statements as a result of new information, future events, or otherwise. These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf.

 Item 1A. RISK FACTORS
 Our businesses involve a high degree of risk. You should consider and read carefully the risks and uncertainties described below together with all of the other information contained in this Annual Report on Form 10-K. If any of the following risks, or any risk described elsewhere in this Annual Report on Form 10-K, actually occur, our business, prospects, financial condition, results of operations, or cash flows could be materially adversely affected. In any such case, the trading price of our common stock could decline. The risks described below are not the only ones facing our company. Additional risks not currently known to us or that we currently deem immaterial may also adversely affect us.
 OPERATING RISKS
 Our operations are subject to operational hazards that could expose us to potentially significant losses.
 Our operations are subject to potential operational hazards and risks inherent in refining operations, in transporting and storing crude oil and refined products, and in producing natural gas and oil. Any of these risks, such as fires, explosions, maritime disasters, security breaches, cyber threats, pipeline ruptures and spills, mechanical failure of equipment, and severe weather and natural disasters at our or third-party facilities could result in business interruptions or shutdowns and damage to our properties and the properties of others. The scientific consensus suggests that some of these physical risks to our facilities and third party facilities, especially risks associated with extreme weather, may increase as a result of climate change. A serious accident at our facilities could also result in serious injury or death to our employees or contractors and could expose us to significant liability for personal injury claims and reputational risk. Any such event or unplanned shutdown could have a material adverse effect on our business, financial condition, and results of operations.
 The volatility of crude oil prices and refined product prices and changes in the demand for such products may have a material adverse effect on our cash flow and results of operations.
 Earnings and cash flows from our refining segment depend on a number of factors, including to a large extent the cost of crude oil and other refinery feedstocks which has fluctuated significantly in recent years. While prices for refined products are influenced by the price of crude oil, the constantly changing margin between the price we pay for crude oil and other refinery feedstocks and the prices we receive for refined products, the crack spread, also fluctuates significantly. The prices we pay and prices we receive depend on numerous factors beyond our control, including the global supply and demand for crude oil, gasoline, and other refined products, which are subject to, among other things:
 • changes in the global economy and the level of foreign and domestic production of crude oil and refined products;
 • availability of crude oil and refined products and the infrastructure to transport crude oil and refined products;
 • local factors, including market conditions, the level of operations of other refineries in our markets, and the volume and price of refined products imported;
 • threatened or actual terrorist incidents (including cyber attacks), acts of war, and other global political conditions;
 • changes in the availability or cost of maritime shipping;
 • pandemics, public health crises, or other widespread emergencies such as COVID-19;
 • government regulations or mandated production curtailments or limitations; and
 • weather conditions, hurricanes, or other natural disasters.
 These actions could result in an increase in the price we pay for crude oil, which may result in a decrease in the expected earnings and cash flows generated by our refining business.
 In addition, we purchase our refinery feedstocks before manufacturing and selling the refined products. Price level changes during the periods between purchasing and selling these refined products could also have a material adverse effect on our business, financial condition, and results of operations.
 Instability in the global economic and political environment can lead to volatility in the cost and availability of crude oil and prices for refined products, which could adversely impact our results of operations.
 Instability in the global economic and political environment can lead to volatility in the cost and availability of crude oil and in the price and demand for refined products. This may place downward pressure on our results of operations. This is particularly true of developments in and relating to oil-producing countries, including terrorist activities, military conflicts, embargoes, internal instability, or actions or reactions of the U.S. or foreign governments in anticipation of, or in response to, such developments. Any such events may limit or disrupt markets, which could negatively impact our ability to access global crude oil commodity flows or sell our refined products.

 Geopolitical conflicts, including the conflict between Russia and Ukraine, could increase the cost of our crude oil feedstocks and affect the demand for our products.
 In February 2022, following Russia's invasion of Ukraine, the U.S. and other countries announced sanctions against Russia, including restrictions on the importation of Russian crude oil. On March 3, 2022, we suspended purchases of Russian crude oil for our Hawaii refinery in response to the Russia-Ukraine conflict. The U.S. and other countries have imposed additional sanctions as the conflict has escalated. Any further sanctions imposed or actions taken by the U.S. or other countries, and any retaliatory measures by Russia in response, such as restrictions on energy supplies from Russia, may increase our costs, reduce our sales and earnings, or otherwise have an adverse effect on our operations. Additionally, conflicts like Russia's invasion of Ukraine and recent attacks on shipping in the Red Sea may exacerbate inflationary pressures, including with respect to commodity prices and energy costs, and disrupt global supply chains. Rapid and significant changes in commodity costs may increase the cost of our crude oil feedstocks and affect the demand for our products.
 Many of our refined products could cause serious injury or death if mishandled or misused by us or our purchasers, or if defects occur during manufacturing.
 While we produce, store, transport, and deliver all of our refined products in a safe manner, many of our refined products are highly flammable or explosive and could cause significant damage to persons or property if mishandled. Defects in our products (such as gasoline or jet fuel) or misuse by us or by end purchasers could lead to fatalities or serious damage to property. We may be held liable for such occurrences, which could have a material adverse effect on our business and results of operations.
 Our business is impacted by increased risks of spills, discharges, or other releases of petroleum or hazardous substances in our refining and logistics operations.
 The operation of refineries, pipelines, and refined products terminals is subject to increased risks of spills, discharges, or other inadvertent releases of petroleum or hazardous substances, and we operate in and around environmentally sensitive coastal waters that are closely regulated and monitored. These events could occur in connection with the operation of our refineries, pipelines, or refined products terminals. If any of these events occur, or is found to have previously occurred, we could be liable for costs and penalties associated with their remediation under federal, state, and local environmental laws or common law, and could be liable for property damage to third parties caused by contamination from releases and spills. The penalties and clean-up costs that we may have to pay for releases or the amounts that we may have to pay to third parties for damages to their property could be significant and have a material adverse effect on our business, financial condition, or results of operations.
 Our operations, including the operation of underground storage tanks, are also subject to the risk of environmental litigation and investigations which could affect our results of operations.
 From time to time, we may be subject to litigation or investigations with respect to environmental and related matters, the costs of which could be material. We operate fueling stations with underground storage tanks used primarily for storing and dispensing refined fuels. In addition, some fueling stations where we sell fuel are owned or operated by third parties who are not under our control. Federal and state regulations and legislation govern the storage tanks and compliance with these requirements can be costly. The operation of underground storage tanks poses certain risks, including leaks. Leaks from underground storage tanks, which may occur at one or more of our fueling stations, may impact soil or groundwater and could result in fines or civil liability for us.
 Our insurance coverage may be inadequate to protect us from the liabilities that could arise in our business.
 We carry property, casualty, business interruption, and other lines of insurance, but we do not maintain insurance coverage against all potential losses. Marine vessel charter agreements do not include indemnity provisions for oil spills, so we also carry marine charterer's liability insurance. We could suffer losses for uninsurable or uninsured risks or in amounts in excess of existing insurance coverage. Claims covered by insurance are subject to deductibles, the aggregate amount of which could be material. Insurance policies are also subject to compliance with certain conditions, the failure of which could lead to a denial of coverage as to a particular claim or the voiding of a particular insurance policy. There also can be no assurance that existing insurance coverage can be renewed at commercially reasonable rates or that available coverage will be adequate to cover future claims. The occurrence of an event that is not fully covered by insurance or failure by one or more insurers to honor its coverage commitments for an insured event could have a material adverse effect on our business, financial condition, and results of operations.

 We are subject to interruptions of supply and increased costs as a result of our reliance on third-party transportation of crude oil and refined products to and from our refineries.
 Our refineries receive and transport crude oil and refined products via tankers, barges, pipelines, and railcars. In addition to environmental risks, we could experience an interruption of supply or an increased cost to deliver refined products to market if such transportation is disrupted because of adverse weather, accidents, governmental regulation or sanctions, or third-party action. A prolonged disruption could have a material adverse effect on our business, financial condition, and results of operations.
 The financial and operating results of our refineries, including the products they refine and sell, can be seasonal.
 Demand for gasoline in the Rockies and Northwest United States is generally higher during the summer months than during the winter months due to seasonal increases in highway traffic. The Montana, Wyoming, and Washington refineries' financial and operating results for the first and fourth calendar quarters may be lower than those for the second and third calendar quarters of each year as a result of this seasonality. Conversely, the demand for the products the Hawaii refinery refines and sells, and the financial and operating results for the Hawaii refinery, are often strongest in the first and fourth calendar quarters.
 We rely upon certain critical information systems for the operation of our business and the failure of any critical information system, including a cybersecurity breach, may result in harm to our business.
 We are heavily dependent on our technology infrastructure and maintain and rely upon certain critical information systems for the effective operation of our business. These information systems include data network and telecommunications, internet access and our websites, and various computer hardware equipment and software applications, including those that are critical to the safe operation of our refineries and our pipelines and terminals. Our retail business collects certain customer data, including credit card numbers, for business purposes. The integrity and protection of our customer, employee, and company data is critical to our business.
 Our information systems are subject to damage or interruption from a number of potential sources including natural disasters, ransomware, software viruses or other malware, power failures, cyber attacks, and other events. To the extent that these information systems are under our control, we have implemented cybersecurity policies designed to address these risks. However, security measures for information systems cannot be guaranteed to be failsafe. Our systems and procedures for protecting against such attacks and mitigating such risks may prove to be insufficient in the future and such attacks could have an adverse impact on our business and operations, including damage to our reputation and competitiveness, remediation costs, litigation, or regulatory. Any compromise of our data security or our inability to use or access these information systems at critical points in time could unfavorably impact the timely and efficient operation of our business and subject us to additional costs and liabilities, which could adversely affect our business, financial condition, and results of operations. In addition, as technologies evolve, and cyber attacks become more sophisticated, we may incur significant costs to upgrade or enhance our security measures to protect against such attacks and we may face difficulties in fully anticipating or implementing adequate preventive measures or mitigating potential harm. Finally, federal legislation relating to cybersecurity threats could impose additional requirements on our operations.
 Climate change may increase the frequency and severity of weather events that could result in severe personal injury, property damage, and environmental damage, which could curtail our operations and otherwise materially adversely affect our cash flows.
 Some scientists have concluded that increasing concentrations of GHG in Earth's atmosphere may produce climate changes that have significant weather-related effects, such as increased frequency and severity of storms, droughts, floods, and other climatic events. If any of those effects were to occur, they could have an adverse effect on our operations, including damages to our refineries, retail locations, logistics assets or other properties from powerful wind or rising waters. We may experience increased insurance costs, or difficulty obtaining adequate insurance coverage, for our assets in areas subject to more frequent severe weather. We may not be able to recoup these increased costs through the cash generated by our business. Extreme weather events could cause damage to property or facilities that could exceed our insurance coverage and our business, financial condition, and results of operations could be adversely affected. Additionally, if we are named in litigation related to climate change, costs or other impacts resulting from such litigation could be material.

 Through our investment in Laramie Energy, we are subject to all of the risks of natural gas and oil exploration and production, but we lack the ability to control Laramie Energy's operations and our ability to extract value is limited.
 Through our investment in Laramie Energy, we are exposed to all of the risks inherent in natural gas and oil exploration and production, including the risks that: exploration and development drilling may not result in commercially productive reserves; the operator may act in ways contrary to our best interest; the marketability of our natural gas products depends mostly on the availability, proximity, and capacity of natural gas gathering systems, pipelines, and processing facilities, which are owned by third parties, as well as adequate water supplies; we have no long-term contracts to sell natural gas or oil; compliance with environmental and other governmental regulatory or legislative requirements could result in increased costs of operation or curtailment, delay, or cancellation of development and producing operations; and a decline in demand for natural gas and oil could adversely affect our financial condition and results of operations.
 REGULATORY RISK
 Meeting the requirements of evolving environmental, health, and safety laws and regulations, including those related to climate change and marine protection, could adversely affect our performance.
 Consistent with the experience of other U.S. refineries, environmental laws and regulations have raised operating costs and may require significant capital investments at our refineries. We may be required to address conditions that may be discovered in the future and require a response. Potentially material expenditures could be required in the future as a result of evolving environmental, health, and safety and energy laws, regulations, or requirements that may be adopted or imposed in the future. Future developments in federal and state laws and regulations governing environmental, health and safety, and energy matters are especially difficult to predict.
 Currently, multiple legislative and regulatory measures to address GHG emissions (including CO2, methane, and NOX) are in various phases of consideration, promulgation, or implementation. These include actions to develop national, statewide, or regional programs, each of which could require reductions in our GHG emissions. Requiring reductions in our GHG emissions could result in increased costs to (i) operate and maintain our facilities, (ii) install new emission controls at our facilities, and/or (iii) administer and manage any GHG emissions programs, including acquiring emission credits or allotments. Requiring reductions in our GHG emissions and increased use of renewable fuels which can be supplied by producers and marketers in other industries that supply alternative forms of energy and fuels to satisfy the requirements of our industrial, commercial, and individual customers could also decrease the demand for our refined products, and could have a material adverse impact on our business, financial condition, and results of operations.
 Additionally, legislation designed to protect animal and plant species, such as the Magnuson amendment to the Marine Mammal Protection Act, may limit or restrict our ability to construct or expand new oil terminals and oil-by-rail infrastructure in the state of Washington, which could have a material impact on our business, financial condition, and results of operations. Finally, federal and state regulations requiring additional GHG-related disclosures could significantly increase our regulatory compliance costs.
 Renewable fuels mandates and other mandates may reduce demand for the petroleum fuels we produce, which could have a material adverse effect on our business results of operations and financial condition.
 The RFS program sets annual quotas for the quantity of renewable fuels that must be blended into transportation fuels consumed in the U.S. A RIN is assigned to each gallon of renewable fuel produced in or imported into the U.S. As a producer of petroleum-based transportation fuels, we are obligated to blend renewable fuels into the petroleum fuels we produce and sell in the U.S. To the extent we do not, we are required to purchase RINs in the market to satisfy our obligations under the RFS program. In addition, as a result of the annual volume mandates, we may experience a decrease in demand for refined products due to refined products being replaced by renewable fuels.
 We are exposed to the volatility in the market price of RINs and are unable to predict the future prices of RINs. RINs prices are dependent upon a variety of factors, including EPA regulations, the availability of RINs for purchase, and levels of transportation fuels produced, which can vary significantly from quarter to quarter. 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 EPA's RFS mandates, our results of operations and cash flows could be adversely affected. The current administration has also been critical of exemptions from the RFS mandates granted to small refineries during the previous administration. While litigation over the issue is currently before various courts, the EPA under the current administration may be less willing to grant such waivers going forward and may increase the RVO in future years. To the extent fewer waivers are granted in the future or the RVO is increased, the demand for and the price of RINs would likely also increase, and our results of operations and cash flows could be adversely affected. In addition, the EPA is considering changes to the existing RFS program regulations and other regulatory

 initiatives under the RFS program that could impact future standards. Although uncertain, any of these events may cause the price of RINs to rise and result in additional costs in connection with RFS compliance. Such increased costs could be material and may have a material adverse impact on our business, financial condition, and results of operations. All RIN transactions are recorded in the EPA Moderated Transaction System ("EMTS"). Under this system, purchasers of RINs are required to self-certify their validity without verification by the EPA, and are responsible for any invalid RINs submitted to the EPA for compliance. We believe that the RINs we purchase are from reputable sources, are valid, and serve to demonstrate compliance with applicable RFS requirements. However, if this belief proves incorrect and the RINs that we purchase are not valid or in compliance with applicable RFS requirements, our financial condition and cash flows may be adversely affected.
 Several states, including Washington and Hawaii, have pursued or are considering initiatives designed to reduce the carbon intensity of the transportation sector by encouraging increased use of renewable fuels or electric vehicles or by requiring reductions in transportation fuel-related GHG emissions in the state. Since 2006, the State of Washington has required that denatured ethanol make up at least 2% of total gasoline sold in the state and that biodiesel comprise at least 2% of total diesel sold in the state, and the Washington Department of Ecology is authorized to increase these requirements if certain conditions are met. In 2020 and 2021 the State of Washington adopted several statutes that are relevant to our operations in the state of Washington including a law approving new regulatory requirements regarding zero emission vehicles and a low-carbon fuel standard designed to reduce the carbon intensity of transportation fuels by twenty percent by 2038. Legislation signed in March of 2020 directed the Washington Department of Ecology to adopt California's vehicle emission standards including requirements to increase zero emission vehicles sold in the state. Washington Department of Ecology adopted by reference California's zero emission vehicle standard starting with model year 2025 in a rule issued on November 29, 2021. In 2014, the State of Hawaii signed a memorandum of understanding with the U.S. Department of Energy to collaborate to produce 70% of the state's energy needs from energy-efficient and renewable sources by 2030 and 100% of the state's energy needs from energy-efficient and renewable sources by 2045. In addition, Hawaii's alternative fuels standard requires the State to facilitate the development of alternate fuels so such fuels provide 20% of highway fuel demand by 2020 and 30% by 2030. Finally, California and a small number of other states have announced a ban on new internal combustion engine-powered cars by 2035. These state actions could reduce demand for our refined petroleum products, which could have a material adverse effect on our business, results of operations, and financial condition.
 Potential legislative and regulatory actions addressing climate change could increase our costs, reduce our revenue and cash flow from natural gas and oil sales, or otherwise alter the way we conduct our business.
 Currently, multiple legislative and regulatory measures to address GHG, including CO2, methane, and NOX, and other emissions are in various phases of consideration, promulgation, or implementation at various levels of the federal and state government. These include actions to develop international, federal, regional, or statewide programs, which could require reductions in our GHG or other emissions, establish a carbon tax and decrease the demand for our refined products. Requiring reductions in these emissions could result in increased costs to (i) operate and maintain our facilities, (ii) install new emission controls at our facilities, and (iii) administer and manage any emissions programs, including acquiring emission credits or allotments.
 For example, in 2015, the U.S., Canada, and the U.K. participated in the United Nations Conference on Climate Change, which led to the creation of the Paris Agreement. The Paris Agreement, which was signed by the U.S. in April 2016, requires countries to review and "represent a progression" in their intended nationally determined contributions (which set GHG emission reduction goals) every five years beginning in 2020. In November 2020, the United States' previously-announced withdrawal from the Paris Agreement became effective. On January 20, 2021, President Biden announced that the United States would be reentering the Paris Agreement. This reentry became effective on February 19, 2021. Restrictions on emissions of methane or carbon dioxide that have been or may be imposed in various U.S. states, at the U.S. federal level, or in other countries could adversely affect the oil and gas industry.
 The EPA has issued a notice of finding and determination that emissions of CO2, methane, and other GHGs present an endangerment to human health and the environment. In response, the EPA has adopted regulations under existing provisions of the federal Clean Air Act that, among other things, establish Prevention of Significant Deterioration ("PSD") construction and Title V operating permit program requiring reviews for GHG emissions from certain large stationary sources. Facilities required to obtain PSD permits for their GHG emissions will also be required to meet "best available control technology" standards, which will be established by the states or, in some instances, by the EPA on a case-by-case basis. In addition, the EPA has adopted rules requiring the monitoring and reporting of GHG emissions from specified large GHG emission sources in the U.S., including petroleum refineries and certain onshore petroleum and natural gas production activities, on an annual basis. We monitor for GHG emissions at our refineries and believe we are in substantial compliance with the applicable GHG reporting requirements. Certain of the third-party drilling and production entities in which we hold a working interest also may be subject

 to reporting of GHG emissions in the U.S. These EPA policies and rulemakings could adversely affect our operations and restrict or delay our ability to obtain air permits for new or modified facilities.
 In addition, from time to time, the U.S. Congress has considered and may in the future consider and adopt "cap and trade" legislation that would establish an economy-wide cap on GHG emissions in the U.S. and would require most sources of GHG emissions to obtain emission "allowances" corresponding to their annual GHG emissions. For those GHG sources that are unable to meet the required limitations, such legislation could impose substantial financial burdens. Any laws or regulations that may be adopted to restrict or reduce GHG emissions would likely require us to incur increased operating costs and could have an adverse effect on demand for our production. The adoption of any legislation or regulations that limits emissions of GHG from our or such drilling and production entities' facilities, equipment, and operations could require us or such entities to incur costs to reduce emissions of GHG associated with our or such entities' operations or could adversely affect demand for the refined petroleum products that we produce or the crude oil or natural gas that such drilling and production entities in which we hold a working interest produce.
 At the state level, Washington and other states have passed low carbon fuel standard legislation and other initiatives, including a cap and invest program, to reduce emissions from the transportation sector. We could also face increased climate-related litigation with respect to our operations or products. If we are unable to pass the costs of compliance on to our customers, sufficient credits are unavailable for purchase, we have to pay a significantly higher price for credits, or we are otherwise unable to meet our compliance obligation, our financial condition and results of operations could be adversely affected.
 Federal, regional, and state climate change and air emissions goals and regulatory programs under the Clean Air Act are complex, subject to change, and create uncertainty due to a number of factors including technological feasibility, legal challenges, and potential changes in federal policy. Nevertheless, stricter regulation can be expected in the future and any of these or similar changes, or regulatory enforcement in connection with such requirements, may have a material adverse impact on our business, results of operations, and financial condition. For more information, please read Note 18—Commitments and Contingencies to our consolidated financial statements under Item 8 of this Form 10-K.

 Regulatory and other requirements concerning the transportation of crude oil and other commodities by rail may cause increases in transportation costs or limit the amount of crude oil that we can transport by rail.
 We rely on a variety of systems to transport crude oil, including rail. Rail transportation is regulated by federal, state, and local authorities. New regulations or changes in existing regulations could result in increased compliance expenditures. For example, in 2019 Washington enacted a law that limits crude oil by rail deliveries through a cap on off-loadings from existing facilities and new specifications regarding the vapor pressure of crude oils permitted to be shipped through the state. These or other regulations that require the reduction of volatile or flammable constituents in crude oil that is transported by rail, change the design or standards for rail cars used to transport the crude oil we purchase, change the routing or scheduling of trains carrying crude oil, or require any other changes that detrimentally affect the economics of delivering North American crude oil by rail, could increase the time required to move crude oil from production areas to our refineries, increase the cost of rail transportation, and decrease the efficiency of shipments of crude oil by rail within our operations. Any of these outcomes could have a material adverse effect on our business, results of operations, and financial condition.
 We will be required to undertake significant environmental remediation and other corrective actions in connection with certain prior acquisitions.
 For example, in connection with the July 14, 2016 purchase of Hermes Consolidated, LLC (d/b/a Wyoming Refining Company) and, indirectly, Wyoming Refining Company's wholly owned subsidiary, Wyoming Pipeline Company, LLC (collectively, "Wyoming Refining" or "WRC") (the "WRC Acquisition"), there are several environmental conditions that will require us to undertake significant remediation efforts and other corrective actions. The Wyoming refinery is subject to a number of consent decrees, orders, and settlement agreements involving the EPA and/or the Wyoming Department of Environmental Quality, some of which date back to the late 1970s and several of which remain in effect, requiring further actions at the Wyoming refinery.
 As is typical of older, small refineries like the Wyoming refinery, the largest cost component arising from these various decrees relates to the investigation, monitoring, and remediation of soil, groundwater, surface water, and sediment contamination associated with the facility's historic operations. Investigative work by Wyoming Refining and negotiations with the relevant agencies as to remedial approaches remain ongoing on a number of aspects of the contamination, meaning that investigation, monitoring, and remediation costs are not reasonably estimable for some elements of these efforts. As of December 31, 2023, we have accrued $14.0 million for the well-understood components of these efforts based on current

 information, approximately one-third of which we expect to incur in the next five years and the remainder to be incurred over approximately 30 years. Additionally, we believe the Wyoming refinery will need to modify or close a series of wastewater impoundments in the next several years and to replace those impoundments with a new wastewater treatment system. Based on current information, reasonable estimates we have received suggest costs of approximately $11.6 million to design and construct a new wastewater treatment system.
 We also assumed certain environmental liabilities associated with the Billings Acquisition, including costs related to hazardous waste corrective measures, and ground and surface water sampling and monitoring. Based on current information, reasonable estimates we have received suggest the aggregate amount of these liabilities to be approximately $18.9 million. We expect to incur these costs over a 20 to 30 year period.
 We may incur significant costs and liabilities resulting from performance of pipeline integrity programs and related repairs.
 Pipeline and Hazardous Materials Safety Administration ("PHMSA") has established a series of rules requiring pipeline operators to develop and implement integrity management programs for hazardous liquid pipelines that, in the event of a pipeline leak or rupture, could affect high consequence areas ("HCAs"), which are areas where a release could have the most significant adverse consequences, including high-population areas, certain drinking water sources, and unusually sensitive ecological areas. These regulations require operators of covered pipelines to:
 • perform ongoing assessments of pipeline integrity;
 • identify and characterize applicable threats to pipeline segments that could impact an HCA;
 • improve data collection, integration, and analysis;
 • repair and remediate the pipeline as necessary; and
 • implement preventive and mitigating actions.
 In addition, certain states have also adopted regulations similar to existing PHMSA regulations for intrastate gathering and transmission lines. These requirements could require us to install new or modified safety controls, pursue additional capital projects, or conduct maintenance programs on an accelerated basis, any or all of which tasks could result in us incurring increased operating costs that could be significant and have a material adverse effect on our financial position or results of operations. Additionally, we are subject to periodic inspection and audit regarding these requirements.
 Moreover, changes to pipeline safety laws by Congress and regulations by PHMSA that result in more stringent or costly safety standards could result in our incurring increased operating costs that could have a material adverse effect on our financial position or results of operations. Finally, while we have incurred certain additional costs associated with operating a pipeline regulated by the Federal Energy Regulatory Commission, our costs to date have not been material.
 Compliance with and changes in tax laws could materially and adversely affect our financial condition, results of operations and cash flows.
 We are subject to extensive tax liabilities imposed by multiple jurisdictions including, without limitation, income taxes, indirect taxes (excise/duty, sales/use, gross receipts, GHG emissions), payroll taxes, franchise taxes, withholding taxes, and ad valorem taxes. New tax laws and regulations and changes in existing tax laws and regulations are continuously being enacted or proposed that could result in increased expenditures for tax liabilities in the future. Many of these liabilities are subject to periodic audits by the respective taxing authority. Although we believe we have used reasonable interpretations and assumptions in calculating our tax liabilities, the final determination of these tax audits and any related proceedings cannot be predicted with certainty. Any adverse outcome of such tax audits or related proceedings could result in unforeseen tax-related liabilities that may, individually or in the aggregate, materially affect our cash tax liabilities, results of operations, and financial condition. Additionally, tax rates or tax interpretations in the various jurisdictions in which we operate may change significantly as a result of political or economic factors beyond our control. For more information, please read Note 18—Commitments and Contingencies to our consolidated financial statements under Item 8 of this Form 10-K.

 BUSINESS RISKS
 The locations of our refineries and related assets in certain limited geographic areas create an exposure to localized economic risks.
 Because of the locations of our refineries in Hawaii, Montana, Washington, and Wyoming, we primarily market our refined products in relatively limited geographic areas. As a result, we are more susceptible to regional economic conditions than the operations of more geographically diversified competitors and any unforeseen events or circumstances that affect our operating areas could also materially adversely affect our revenues and our business and operating results. These factors include, among other things, changes in the economy, weather conditions, demographics and population, refined product mix demand, increased supply of refined products from competitors, and reductions in the supply of crude oil.
 We must make substantial capital expenditures at our refineries and related assets to maintain their reliability and efficiency. 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 adversely affected.
 Our refineries and related assets have been in operation for many years. Equipment, even if properly maintained, may require significant capital expenditures and expenses to keep the refineries operating at optimum efficiency. These costs do not result in increases in unit capacities, but rather are focused on trying to maintain safe, reliable operations.
 Delays or cost increases related to the engineering, procurement, and construction of new facilities, or improvements and repairs to our existing facilities and equipment, could have a material adverse effect on our business, financial condition, or results of operations. Such delays or cost increases may arise as a result of unpredictable factors in the marketplace, many of which are beyond our control, including:
 • denial or delay in obtaining regulatory approvals and/or permits;
 • difficulties in executing the capital projects;
 • unplanned increases in the cost of equipment, materials, or labor;
 • disruptions in transportation of equipment and materials;
 • severe adverse weather conditions, natural disasters, or other events (such as equipment malfunctions, explosions, fires, or spills) affecting our facilities, or those of our 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
 • non-performance or force majeure by, or disputes with, our vendors, suppliers, contractors, or sub-contractors.
 Any one or more of these occurrences noted above could have a significant impact on our business. If we are unable to make up the delays or to recover the related costs, or if market conditions change, it could materially and adversely affect our financial position, results of operations, or cash flows.
 The retail market is diverse and highly competitive. Aggressive competition and the development of alternative fuels could adversely impact our business.
 We face strong competition in the market for the sale of retail gasoline, diesel fuel, and merchandise. Our competitors include outlets owned or operated by fully integrated major oil companies or their dealers and other well-recognized national or regional retail outlets, often selling products at very competitive prices. We compete with a number of integrated national and international oil companies who produce crude oil, some of which is used in their refining operations. Unlike these oil companies, we must purchase all of our crude oil from unaffiliated sources. Because these oil companies benefit from increased commodity prices, have greater access to capital, and have stronger capital structures, they are able to better withstand poor and volatile market conditions, such as a lower refining margin environment, shortages of crude oil and other feedstocks, or extreme price fluctuations.
 Additionally, non-traditional retailers such as supermarkets, club stores, and mass merchants are also in the retail business, and these non-traditional gasoline retailers have obtained a significant share of the transportation fuels market. These retailers may use integration of operations, greater financial resources, promotional pricing or discounts, or other advantages to withstand volatile market conditions or levels of no or low profitability. The development of alternative and competing fuels in the retail market could also adversely impact our business. Increased competition from these alternatives as a result of governmental regulations, technological advances, and consumer demand could have an impact on pricing and demand for our products and our profitability.

 If we are unable to obtain crude oil supplies for our refineries without the benefit of our Supply and Offtake Agreement, LC Facility, and ABL Credit Facility, the capital required to finance our crude oil supply could negatively impact our liquidity.
 All of the crude oil delivered at our Hawaii refinery is subject to our Supply and Offtake Agreement with J. Aron and certain crude deliveries at our Hawaii refinery are subject to the LC Facility. Deliveries of crude oil at our other refineries are subject to the ABL Credit Facility. If we are unable to obtain our crude oil supply for our refineries under these agreements, our exposure to crude oil pricing risks may increase as the number of days between when we pay for the crude oil and when the crude oil is delivered to us increases. Such increased exposure could negatively impact our liquidity position due to the increase in working capital used to acquire crude oil inventory for our refineries.
 The Supply and Offtake Agreement and LC Facility expose us to counterparty credit and performance risk.
 We have the Supply and Offtake Agreement with J. Aron, pursuant to which J. Aron will intermediate crude oil supplies and refined product inventories at our Hawaii refinery. J. Aron will own all of the crude oil in our tanks and substantially all of our refined product inventories prior to our sale of the inventories. Upon termination of the Supply and Offtake Agreement, which terminates on May 31, 2024, we are obligated to repurchase all crude oil and refined product inventories then owned by J. Aron and located at the specified storage facilities at then current market prices. This repurchase obligation could have a material adverse effect on our business, results of operations, or financial condition. Our agreement with J. Aron also requires us to pay substantial interest expense associated with the facility, which will increase in a rising crude oil price and interest rate environment. We also have the LC Facility which is intended to finance and provide credit support for certain of PHR's purchases of crude oil. An adverse change in the business, results of operations, liquidity, or financial condition of one of our counterparties could adversely affect the ability of such counterparty to perform its obligations, which could consequently have a material adverse effect on our business, results of operations, or liquidity and, as a result, our business and operating results.
 Inadequate liquidity could materially and adversely affect our business operations in the future.
 If our cash flow and capital resources are insufficient to fund our obligations, we may be forced to reduce our capital expenditures, seek additional equity or debt capital, or restructure our indebtedness. We cannot assure you that any of these remedies could, if necessary, be affected on commercially reasonable terms, or at all. Our liquidity is constrained by our need to satisfy our obligations under our debt agreements, the Supply and Offtake Agreement, and the LC Facility. The availability of capital when the need arises will depend upon a number of factors, some of which are beyond our control. These factors include general economic and financial market conditions, the crack spread, natural gas and crude oil prices, our credit ratings, interest rates, market perceptions of us or the industries in which we operate, our market value, and our operating performance. We may be unable to execute our long-term operating strategy if we cannot obtain capital from these or other sources when the need arises.
 Our ability to generate cash and repay our indebtedness or fund capital expenditures depends on many factors beyond our control and any failure to do so could harm our business, financial condition, and results of operations.
 Our ability to fund future capital expenditures and repay our indebtedness when due will depend on our ability to generate sufficient cash flow from operations, borrowings under our debt agreements, and distributions from our subsidiaries. To a certain extent, this is subject to general economic, financial, competitive, legislative, and regulatory conditions and other factors that are beyond our control, including crack spreads.
 We cannot assure you that our businesses will generate sufficient cash flow from operations, that our subsidiaries can or will make sufficient distributions to us, or that future borrowings will be available to us in an amount sufficient to repay our indebtedness or fund our other liquidity needs. If our cash flow and capital resources are insufficient to fund our needs, we may be forced to reduce our planned capital expenditures, sell assets, seek additional equity or debt capital, or restructure our debt. We cannot assure you that any of these remedies could, if necessary, be affected on commercially reasonable terms, or at all, which could cause us to default on our obligations and could impair our liquidity.
 Our substantial level of indebtedness could adversely affect our financial condition.
 We have a substantial amount of indebtedness, which requires significant interest payments. As of December 31, 2023, we had $650.9 million of indebtedness and Interest expense and financing costs, net for the year ended December 31, 2023 was $72.5 million.

 Our substantial level of indebtedness could have important consequences, including the following:
 • we must use a substantial portion of our cash flow from operations to pay interest and principal on our indebtedness and obligations under the Supply and Offtake Agreement and LC Facility, which reduces funds available to us for other purposes, such as working capital, capital expenditures, other general corporate purposes, and potential acquisitions;
 • our ability to refinance such indebtedness or to obtain additional financing for working capital, capital expenditures, acquisitions, or general corporate purposes may be impaired;
 • our leverage may be greater than that of some of our competitors, which may put us at a competitive disadvantage and reduce our flexibility in responding to current and changing industry and financial market conditions;
 • we may be more vulnerable to economic downturns and adverse developments in our business; and
 • we may be unable to comply with financial and other restrictive covenants in our debt agreements, some of which require us to maintain specified financial ratios and limit our ability to incur additional debt and sell assets, which could result in an event of default that, if not cured or waived, would have an adverse effect on our business and prospects and could result in bankruptcy.
 Our ability to meet expenses, to remain in compliance with the covenants under our debt agreements, and to make future principal and interest payments in respect of our debt depends on, among other things, our operating performance, competitive developments, and financial market conditions, all of which are significantly affected by financial, business, economic, and other factors. We are not able to control many of these factors. If industry and economic conditions deteriorate, our cash flow may not be sufficient to allow us to pay principal and interest on our debt and meet our other obligations.
 This increase in our indebtedness may reduce our flexibility to respond to changing business and economic conditions or to fund capital expenditure or working capital needs because we will require additional funds to service our outstanding indebtedness and may not be able to obtain additional financing.
 Despite our current debt levels, we may still incur substantially more debt or take other actions which would intensify the risks associated with our substantial leverage.
 Despite our current consolidated debt levels, we may be able to incur significant additional indebtedness in the future. Although our debt agreements contain restrictions on the incurrence of additional indebtedness and entering into certain types of other transactions, these restrictions are subject to a number of qualifications and exceptions. Additional indebtedness incurred in compliance with these restrictions could be substantial. These restrictions also do not prevent us or our subsidiaries from incurring obligations, such as trade payables, that do not constitute indebtedness as defined under our debt agreements. To the extent new debt is added to our current debt levels, the substantial leverage risks associated with our indebtedness would increase.
 Our debt agreements impose significant operating and financial restrictions on us.
 Our debt agreements impose, and the terms of any future debt may impose, significant operating and financial restrictions on us. These restrictions, among other things, may limit our ability to:
 • pay dividends or distributions, repurchase equity, prepay junior debt, and make certain investments, loans, or acquisitions;
 • incur additional debt, make guarantees of debt, or issue certain disqualified stock and preferred stock;
 • sell or otherwise dispose of assets, including capital stock of subsidiaries;
 • incur liens;
 • enter into certain hedging transactions;
 • consummate fundamental changes, merge or consolidate with another company, sell all or substantially all assets, or alter the business;
 • enter into certain transactions with affiliates; and
 • enter into agreements that would restrict the ability of our subsidiaries to pay dividends or distributions.
 All of these covenants may adversely affect our ability to finance our operations, meet or otherwise address our capital needs, pursue business opportunities, react to market conditions, or otherwise restrict activities or business plans. A breach of any of these covenants could result in a default in respect of the related indebtedness. If a default occurs, the requisite lenders could elect to declare the indebtedness, together with accrued interest and other fees, to be immediately due and payable and proceed against any collateral securing that indebtedness. If repayment of our indebtedness is accelerated as a result of such default, we cannot assure you that we would have sufficient assets or access to credit to repay such indebtedness.

 We may incur losses and incur additional costs as a result of our forward-contract activities and derivative transactions.
 We enter into derivative contracts from time to time primarily to reduce our exposure to fluctuations in interest rates and in the price of crude oil and refined products. If the instruments we use to hedge our exposure are not effective, or if our counterparties are unable to satisfy their obligations to us, we may incur losses. We may also be required to incur additional costs in connection with future regulation of derivative instruments to the extent such regulation is applicable to us. Additionally, our commodity derivative activities may produce significant period-to-period earnings volatility that is not necessarily reflective of our underlying operational performance.
 Our variable rate indebtedness subjects us to interest rate risk, which could cause our debt service obligations to increase significantly and otherwise impact our ability to incur indebtedness for acquisitions and working capital needs.
 We are subject to interest rate risk in connection with borrowings under certain of our debt agreements as well as our Supply and Offtake Agreement and LC Facility, which bear interest at variable rates. Interest rate changes will not affect the market value of indebtedness incurred under such debt agreements, but could affect the amount of our interest payments and, accordingly, our future earnings and cash flows, assuming other factors are held constant. Increases in interest rates could also impact our ability to incur indebtedness to fund acquisitions and working capital needs. Since 2022, interest rates have been significantly higher than in recent years and a significant increase in prevailing interest rates that results in a substantial increase in the interest rates applicable to our indebtedness could substantially increase our interest expense and have a material adverse effect on our financial condition, results of operations, and cash flows.
 We cannot be certain that our net operating loss tax carryforwards will continue to be available to offset our tax liability.
 As of December 31, 2023, we estimated that we had approximately $0.9 billion of net operating loss ("NOL") tax carryforwards. In order to utilize the NOLs, we must generate taxable income that can offset such carryforwards. The availability of NOLs to offset taxable income would be substantially reduced or eliminated if we were to undergo an "ownership change" within the meaning of Section 382 of the Internal Revenue Code of 1986, as amended (the "Code"). We will be treated as having had an "ownership change" if there is more than a 50% increase in stock ownership during any three year "testing period" by "5% shareholders." In order to help us preserve our NOLs, our certificate of incorporation contains stock transfer restrictions designed to reduce the risk of an ownership change for purposes of Section 382 of the Code. We expect that the restrictions will remain in place for the foreseeable future. We cannot assure you, however, that these restrictions will prevent an ownership change.
 Our ability to utilize a significant portion of our NOLs to offset future taxable income is subject to various limitations, including that certain NOLs will expire in various amounts, if not used, between 2030 through 2037. During 2018, the Internal Revenue Service ("IRS") completed an audit of our tax returns for the tax years ending 2014 through 2016, which included those returns for the years in which the losses giving rise to the NOLs were reported. Although the IRS made no challenge of the availability of our NOLs during this audit, we cannot assure you that we would prevail if the IRS were to challenge the availability of the NOLs in the event of future audits. If the IRS were successful in challenging our NOLs, all or some portion of the NOLs would not be available to offset any future consolidated income, which would negatively impact our results of operations and cash flows. Certain provisions of the Tax Cuts and Jobs Act, enacted in 2017, may also limit our ability to utilize our net operating tax loss carryforwards.
 We may be unable to successfully identify, execute, or effectively integrate future acquisitions, which may negatively affect our results of operations.
 We will continue to pursue acquisitions in the future. Although we regularly engage in discussions with, and submit proposals to, acquisition candidates, suitable acquisitions may not be available in the future on reasonable terms. If we do identify an appropriate acquisition candidate, we may be unable to successfully negotiate the terms of an acquisition, finance the acquisition, or, if the acquisition occurs, effectively integrate the acquired business into our existing businesses. Negotiations of potential acquisitions and the integration of acquired business operations may require a disproportionate amount of management's attention and our resources. Even if we complete additional acquisitions, continued acquisition financing may not be available or available on reasonable terms, any new businesses may not generate the anticipated level of revenues, the anticipated cost efficiencies, or synergies may not be realized, and these businesses may not be integrated successfully or operated profitably. Our inability to successfully identify, execute, or effectively integrate future acquisitions may negatively affect our results of operations.

 Acquisitions may prove to be worth less than we paid because of uncertainties in evaluating potential liabilities.
 Our recent growth is due in large part to acquisitions, such as the acquisitions of our Montana refining business. We expect acquisitions to be instrumental to our future growth. Successful acquisitions require an assessment of a number of factors, including estimates of potential unknown and contingent liabilities. Such assessments are inexact and their accuracy is inherently uncertain. In connection with our assessments, we perform due diligence reviews of acquired businesses and assets that we believe are generally consistent with industry practices. However, such reviews will not reveal all existing or potential problems. In addition, our reviews may not permit us to become sufficiently familiar with potential environmental problems or other contingent and unknown liabilities that may exist or arise. As a result, there may be unknown and contingent liabilities related to acquired businesses and assets of which we are unaware. We could be liable for unknown obligations relating to acquisitions for which indemnification is not available, which could materially adversely affect our business, results of operations, and cash flows.
 A substantial portion of our refining workforce is unionized and we may face labor disruptions that would interfere with our operations.
 As of December 31, 2023, we employed 1,814 people, 331 of whom are covered by collective bargaining agreements. At our Hawaii, Washington, and Montana refineries, all 331 employees covered by collective bargaining agreements are represented by the USW with collective bargaining agreements effective through January 31, 2026. We also employ three employees in Montana in our Rocky Mountain Pipeline & Terminals business that are represented by the Rocky Mountain Union ("RMU") with a collective bargaining agreement effective through October 1, 2025. However, we may not be able to prevent a strike or work stoppage in the future and any such work stoppage could cause disruptions in our business and have a material adverse effect on our business, financial condition, results of operations, and cash flows.
 Changes in the availability of and the cost of labor could adversely affect our business.
 Changes in labor markets due to various factors, including inflationary pressures, have increased the competition for recruiting and retaining talent. As a result of these factors, our business could be adversely impacted by increases in labor, health care, and benefits costs necessary to attract and retain high quality employees with the right skill sets to meet our needs. In addition, our wages and benefits programs may be insufficient to attract and retain top performing employees, especially in a rising wage market. Any failure by us to attract, develop, retain, motivate, and maintain good relationships with qualified individuals could adversely affect our business and results of operations.
 Adverse changes in global economic conditions and the demand for transportation fuels may impact our business and financial condition in ways that we currently cannot predict.
 A recession or prolonged economic downturn would adversely affect the business and economic environment in which we operate. These conditions increase the risks associated with the creditworthiness of our suppliers, customers, and business partners. The consequences of such adverse effects could include interruptions or delays in our suppliers' performance of our contracts, reductions and delays in customer purchases, delays in or the inability of customers to obtain financing to purchase our products, and bankruptcy of customers. Any of these events may adversely affect our financial condition, cash flows, and profitability.

 RISKS RELATED TO OUR COMMON STOCK
 Because we have no near term plans to pay cash dividends on our common stock, investors must look solely to stock appreciation for a return on their investment in us.
 We have never declared or paid any cash dividends on our common stock. We currently intend to retain all available funds and any future earnings for use in the operation and expansion of our business and do not anticipate declaring or paying any cash dividends on our common stock in the near term. Any future determination as to the declaration and payment of cash dividends will be at the discretion of our board of directors and will depend on then-existing conditions, including our financial condition, results of operations, contractual restrictions, capital requirements, business prospects, and other factors that our board of directors considers relevant.
 If securities or industry analysts do not publish research or reports about our business, if they adversely change their recommendations regarding our common stock, or if our operating results do not meet their expectations, our stock price could decline.

 The trading market for our common stock is influenced by the research and reports that industry or securities analysts publish about us or our business. If one or more of these analysts cease coverage of our company or fail to publish reports on us regularly, we could lose visibility in the financial markets, which in turn could cause our stock price or trading volume to decline. Moreover, if one or more of the analysts who cover our company downgrades our common stock or if our operating results do not meet their expectations, our stock price could decline.
 The price of our common stock historically has been volatile. This volatility may affect the price at which you could sell your common stock.
 The market price for our common stock has varied between a high of $37.02 on August 11, 2023, and a low of $20.66 on May 5, 2023, during the year ended December 31, 2023. This volatility may affect the price at which you could sell your common stock. Our stock price is likely to continue to be volatile and subject to significant price and volume fluctuations in response to market and other factors; variations in our quarterly operating results from our expectations or those of securities analysts or investors; downward revisions in securities analysts' estimates; and announcements by us or our competitors of significant acquisitions, strategic partnerships, joint ventures, or capital commitments.
 An impairment of an equity investment, a long-lived asset, or goodwill could reduce our earnings or negatively impact the value of our common stock.
 Consistent with U.S. generally accepted accounting principles ("GAAP"), we evaluate our goodwill for impairment at least annually and our equity investments and long-lived assets, including intangible assets with finite useful lives, whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. For the investments we account for under the equity method, such as Laramie Energy, the impairment test requires us to consider whether the fair value of the equity investment as a whole, not the underlying net assets, has declined and whether that decline is other than temporary. If we determine that an other-than-temporary impairment is indicated, we would be required to recognize a non-cash charge to earnings with a correlative effect on equity and balance sheet leverage as measured by debt to total capitalization. Any impairment charges could have a negative impact on the price of our common stock. Additionally, there can be no assurance that no future impairment charge will be made with respect to our equity investments, goodwill, and long-lived assets.
 The market for our common stock has been historically illiquid, which may affect your ability to sell your shares.
 The volume of trading in our common stock has historically been low. The lack of substantial liquidity can adversely affect the price of our stock at a time when you might want to sell your shares. There is no guarantee that an active trading market for our common stock will develop or be maintained on the NYSE, or that the volume of trading will be sufficient to allow for timely trades. Investors may not be able to sell their shares quickly or at the latest market price if trading in our stock is not active or if trading volume is limited. In addition, if trading volume in our common stock is limited, trades of relatively small numbers of shares may have a disproportionate effect on the market price of our common stock.
 Delaware law, our charter documents, and concentrated stock ownership may impede or discourage a takeover, which could reduce the market price of our common stock.
 We are a Delaware corporation and the anti-takeover provisions of Delaware law impose various impediments to the ability of a third party to acquire control of us, even if a change in control would be beneficial to our existing stockholders. For example, the change in ownership limitations contained in Article 11 of our certificate of incorporation could have the effect of discouraging or impeding an unsolicited takeover proposal. In addition, our board of directors or a committee thereof has the power, without stockholder approval, to designate the terms of one or more series of preferred stock and issue shares of preferred stock. The ability of our board of directors or a committee thereof to create and issue a new series of preferred stock and certain provisions of Delaware law and our certificate of incorporation and bylaws could impede a merger, takeover, or other business combination involving us or discourage a potential acquirer from making a tender offer for our common stock, which, under certain circumstances, could reduce the market price of our common stock.
 As of January 23, 2024, Blackrock, Inc., together with its affiliates, owned or had the right to acquire approximately 14.3% of our outstanding common stock. This level of ownership of shares of our common stock could have the effect of discouraging or impeding an unsolicited acquisition proposal.

 We may issue preferred stock with terms that could adversely affect the voting power or value of our common stock and any future issuances of our common stock may reduce our stock price.
 Our certificate of incorporation authorizes us to issue, without the approval of our stockholders, one or more classes or series of preferred stock having such designations, preferences, limitations, and relative rights, including preferences over our common stock respecting dividends and distributions, as our board of directors may determine. The terms of one or more classes or series of preferred stock could adversely impact the voting power or value of our common stock.
 Additionally, we are not restricted from issuing additional shares of common stock, or securities convertible into common stock, under a registration statement declared effective by the SEC. We cannot predict the size of future issuances of our common stock. However, one or more large issuances of our common stock, or securities convertible into our common stock, may adversely affect the prevailing market price of our common stock.
 Investor sentiment towards climate change, fossil fuels, sustainability, and other Environmental, Social, and Governance ("ESG") matters could adversely affect our business and our stock price.
 There have been efforts in recent years aimed at the investment community, including investment advisors, sovereign wealth funds, public pension funds, universities, and other groups, to promote the divestment of shares of energy companies, as well as to pressure lenders and other financial services companies to limit or curtail activities with energy companies. As a result, some financial intermediaries, investors, and other capital markets participants have reduced or ceased lending to, or investing in, companies that operate in industries with higher perceived environmental exposure, such as the energy industry. If divestment efforts are continued, the price of our common stock or debt securities, and our ability to access capital markets or to otherwise obtain new investment or financing, may be negatively impacted.
 Members of the investment community are also increasing their focus on ESG practices and disclosures, including practices and disclosures related to GHG emissions and climate change in the energy industry in particular, and diversity and inclusion initiatives and governance standards among companies more generally. As a result, we may face increasing pressure regarding our ESG practices and disclosures. Additionally, members of the investment community may screen companies such as ours for ESG performance before investing in our common stock or debt securities or lending to us. Over the past few years there has also been an acceleration in investor demand for ESG investing opportunities, and many large institutional investors have committed to increasing the percentage of their portfolios that are allocated towards ESG-focused investments. As a result, there has been a proliferation of ESG-focused investment funds seeking ESG-oriented investment products.
 If we are unable to meet the ESG standards or investment or lending criteria set by these investors and funds, we may lose investors, investors may allocate a portion of their capital away from us, our cost of capital may increase, the price of our common stock and debt securities may be negatively impacted, and our reputation may also be negatively affected.

 Item 1B. UNRESOLVED STAFF COMMENTS
 None.

 Item 1C. CYBERSECURITY
 We maintain a cybersecurity program that is reasonably designed to protect our information, and that of our customers, against cybersecurity threats that could have material adverse effects on the integrity and effectiveness of our information systems.
 The Audit Committee of our Board of Directors oversees the Company's enterprise risk management process, including the management of risks arising from cybersecurity threats. The Audit Committee typically reviews the measures implemented by the Company to identify and mitigate these risks on a quarterly basis. As part of such reviews, the Audit Committee receives reports and presentations from the Company's Chief Information Officer (CIO) that address a wide range of topics, including recent developments, evolving standards, oversight of third-party vendors, and technological trends related to cybersecurity. The full Board of Directors often attends these presentations. Additionally, at least once each year the CIO briefs the Audit Committee on the results of an independent third-party assessment of the Company's cybersecurity and the Company's information technology incident response and recovery plan.
 At the management level, our cybersecurity strategy is managed by the CIO. The CIO's extensive experience in technology and risk management, including prior work experience in cybersecurity, complemented by other members of our information technology department and third-party vendors, form the backbone of our cybersecurity capability. Our

 cybersecurity program is based on recognized best practices and standards for cybersecurity and information technology, including the National Institute of Standards and Technology Cybersecurity Framework. Cybersecurity incidents that meet established reporting thresholds are escalated within the Company to the CIO and the Company's executive leadership team and, where appropriate, reported to Audit Committee and Board of Directors.
 Cybersecurity threats and related incidents have not had a material impact on the company to date, but future cybersecurity incidents could have a material effect on our business, financial condition, and results of operations. While we have not experienced any material cybersecurity incidents, there can be no guarantee that we will not be the subject of future successful attacks. Additional information on cybersecurity risks we face can be found in Part I, Item 1A. — Risk Factors.

 Item 2. PROPERTIES
 Please read "Item 1. — Business" of this Form 10-K for the location and general character of the properties used in our refining, logistics, and retail segments. Our corporate headquarters are located at 825 Town & Country Lane, Suite 1500, Houston, Texas 77024. We believe that these properties and facilities are adequate for our operations and are maintained in a good state of repair.

 Natural Gas and Oil Properties
 Laramie Energy
 All of the assets held by Laramie Energy are located in Garfield, Mesa, and Rio Blanco counties, Colorado. All of the natural gas, natural gas liquids, and condensate are produced primarily from the Mesaverde formation and to a lesser extent the Mancos formation and some of the acreage is contiguous. The geology of the Piceance Basin is characterized as highly consistent and predictable over large areas, which generally equates to reliable timing and cost expectations during drilling and completion activities, as well as minimal well-to-well variance in production and reserves when completed with the same methodology. During the year ended December 31, 2023, we resumed the application of the equity method of accounting for our investment in Laramie Energy. As of December 31, 2023, the balance of our investment in Laramie Energy on our consolidated balance sheets was $14.3 million.
 Other
 We also own certain immaterial minority interests in wells located in Colorado.

 Item 3. LEGAL PROCEEDINGS
 From time to time, we may be involved in litigation relating to claims arising out of our operations in the normal course of our business. Except as described in Note 18—Commitments and Contingencies to our consolidated financial statements under Item 8 of this Form 10-K, as of the date of this Annual Report on Form 10-K, no legal proceedings are pending against us that we believe individually or collectively could have a materially adverse effect upon our financial condition, results of operations, or cash flows.

 Item 4. MINE SAFETY DISCLOSURES
 Not applicable.

 Item 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND COMPANY PURCHASES OF EQUITY SECURITIES
 Market Information
 On February 20, 2018, our common stock began trading on the NYSE under the symbol "PARR." Prior to that date, our common stock was traded on the NYSE American under the symbol "PARR." As of February 22, 2024, there were 133 common stockholders of record. On February 22, 2024, the closing price of our common stock was $38.40 per share on the NYSE.
 Dividends
 We have not paid dividends on our common stock and we do not expect to do so in the foreseeable future.
 Stock Performance Graph
 The following performance graph and related information shall not be deemed "soliciting material" or "filed" with the SEC, nor shall such information be deemed to be incorporated by reference into any future filings under the Securities Act of 1933 or the Securities Exchange Act of 1934, each as amended.
 This performance graph and the related textual information are based on historical data and are not indicative of future performance. The following line graph compares the cumulative total return on an investment in our common stock against the cumulative total return of the S&P 500 Composite Index and an index of peer companies (that we selected) for the five fiscal years ended December 31, 2023. The performance graph of our peer group is weighted by market value at the beginning of the period and our peer group consists of the following companies: Calumet Specialty Products Partners, L.P., Casey's General Stores, Inc., Crossamerica Partners, L.P., CVR Energy, Inc., Darling Ingredients Inc., Delek US Holdings, Inc., Green Plains Inc., HF Sinclair Corp, Nustar Energy, L.P., Parkland Corp, PBF Energy, Inc., Stepan Company, Sunoco, L.P., Tronox Holdings, PLC, and Vertex Energy, Inc.

 *$100 invested on December 31, 2018 in stock or index, including reinvestment of dividends.

 Recent Sales of Unregistered Securities
 During the year ended December 31, 2023, we did not have any sales of securities in transactions that were not registered under the Securities Act that have not been reported on Form 8-K or Form 10-Q.
 Company Purchases of Equity Securities
 The following table sets forth certain information with respect to repurchases of our common stock during the quarter ended December 31, 2023:

 Period
 Total number of shares (or units) purchased (1)
 Average price paid per share (or unit)
 Total number of shares (or units) purchased as part of publicly announced plans or programs (1)
 Maximum number (or approximate dollar value) of shares (or units) that may yet be purchased under the plans or programs (1)

 October 1 - October 31, 2023
 230,236
 $
 32.69
 229.263
 $
 206,060,840

 November 1 - November 30, 2023
 438,141
 33.46
 438,141
 191,400,332

 December 1 - December 31, 2023
 284,379
 33.66
 284,261
 181,831,998

 Total
 952,756
 $
 33.33
 951,665
 $
 181,831,998

 ________________________________________________
 (1)On November 10, 2021, the Board authorized and approved a share repurchase program for up to $50 million of the currently outstanding shares of the Company's common stock, with no specified end date. On August 2, 2023, the Board approved expanding the Company's share repurchase authorization from $50 million to $250 million. During the year ended December 31, 2023, 1,841 thousand shares were repurchased under this share repurchase program for a total of $62.1 million. Shares repurchased that were not associated with the share repurchase program were surrendered by employees to pay taxes withheld upon the vesting of restricted stock awards. Please read Note 19—Stockholders' Equity to our consolidated financial statements under Item 8 of this Form 10-K for further information.

 Item 6. [RESERVED]

 Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 Overview
 We are a growing energy company based in Houston, Texas, that provides both renewable and conventional fuels to the western United States. For more information, please read "Part I –Item 1. — Business—Overview" of this Form 10-K.
 Known Trends or Uncertainties
 While the market indices presented below under "Item 7. — Management's Discussion and Analysis of Financial Condition and Results of Operations — Results of Operations" are representative of the results of our refineries, each refinery's realized gross margin on a per barrel basis will differ from the benchmark due to a variety of factors that affect the performance of the specific refinery. These factors include, but are not limited to, the actual type and timing of crude oil throughput; product yields; transportation and storage costs; fuel burn; product premiums or discounts; inventory fluctuations; feedstock and product purchases; commodity price risk-management activities; crude oil purchase financing activities; and other factors not reflected in the benchmark refining margin. We operate in logistically complex, niche markets and, as such, each of our refineries has unique cost advantages and disadvantages as compared to their respective relevant market indices.
 Recent Events Affecting Comparability of Periods
 Inflation. Energy prices are, among other factors, indicators of inflation, and the U.S. Federal Reserve (the "Fed") has taken significant steps to curb inflation, and continued to increase interest rates in 2023, from near zero percent at the beginning of 2022 to a range of 5.25% to 5.5% in December 2023. These actions by the Fed acted to lower U.S. inflation rates, which have decreased 3.4% year over year as of the December inflation report released in January 2024. In 2023, the U.S. retail price for regular-grade gasoline averaged $3.52 per gallon, a decrease from gasoline price highs of approximately $5.01 per gallon in summer 2022. This decline was due, in part, to lower crude oil prices in 2023 compared to 2022 and higher gasoline inventories in the second half of 2023. The overall energy index decreased to negative 2.0% year over year as of December 2023. While inflation has improved relative to prior years, we do not believe that inflation has had a material effect on our business, financial condition or results of operations in 2023. If our costs were to become subject to significant inflationary pressures, we may not be able to fully offset such higher costs through price increases, or price increases could lead to a decline in demand for our products, which could have a material effect on our business, financial condition, or results of operations.
 The COVID-19 Pandemic. Subsequent to the pandemic, and various preventive and mitigating measures taken in response, refined product demand has largely returned to 2019 levels. Despite global additions to refining capacity, the availability of refining capacity has not kept pace with demand, and global refinery utilization is above normal levels. Consequently, refining product margins have been consistently above pre-pandemic margins since the spring of 2022. Another pandemic event could cause a return to severe restrictions, leading to a deterioration of macroeconomic conditions and our industry. For more information, please read "Item 1. — Business — Markets" of this Form 10-K.
 Geopolitical Conflicts. Given the nature of our operations, including sourcing crude oil and feedstocks, geopolitical conflicts may affect our business and results of operations. The Russia-Ukraine war, the Israel-Palestine conflict, Houthi attacks in the Red Sea, and Iranian activities in the Strait of Hormuz have all disrupted global trade patterns, increased crude oil price volatility, and increased freight costs and delivery times.
 We continue to actively monitor the impact of these and other global situations on our people, operations, financial condition, liquidity, suppliers, customers, and industry, and are actively responding to the impacts that these matters have on our business. Please read "Item 1A. — Risk Factors" for more information on risks and uncertainties, including those related to economic factors, and their potential impacts on our business.

 Results of Operations

 Year Ended December 31, 2023 Compared to Year Ended December 31, 2022
 Net Income. Our financial results for the year ended December 31, 2023 improved from a net income of $364.2 million for the year ended December 31, 2022 to $728.6 million for the year ended December 31, 2023. The increase was driven by a $274.3 million increase in refining segment operating income, an increase of $116.0 million in income tax benefit, and a $15.7 million increase in logistics segment operating income, partially offset by a $29.0 million increase in general and administrative expenses, a $13.8 million increase in acquisitions and integration expenses related to our Billings Acquisition,

 and a $2.4 million increase in expenses related to Par West operations and redevelopment. Please read the discussions of segment and consolidated results below for additional information.
 Adjusted EBITDA and Adjusted Net Income. For the year ended December 31, 2023, Adjusted EBITDA was $696.2 million compared to $643.4 million for the year ended December 31, 2022. The improvement was primarily related to an increase of $54.7 million in our refining segment, an increase of $22.3 million in our logistics segment, and an increase of $8.0 million in our retail segment, partially offset by a decrease of $32.3 million in our corporate segment. Please read the discussion of segment results below for additional information.
 For the year ended December 31, 2023, Adjusted Net Income was $501.2 million compared to $474.7 million for the year ended December 31, 2022. The improvement was primarily related to the same factors described above for the increase in Adjusted EBITDA partially offset by a $20.0 million increase in depreciation and amortization.
 Year Ended December 31, 2022 Compared to Year Ended December 31, 2021
 Net Income (Loss). Our financial results for the year ended December 31, 2022 improved from a net loss of $81.3 million for the year ended December 31, 2021 to net income of $364.2 million for the year ended December 31, 2022. The improvement was primarily driven by widened product crack spreads across all of our refineries and a favorable change in the valuation of the embedded derivatives related to our inventory financing agreements driven by changes in commodity prices. These improvements were partially offset by unfavorable purchased product and crude oil differentials, unfavorable FIFO adjustments, increased intermediation fees of $79.0 million, and a $54.7 million increase in RINs expenses. Other factors impacting our results period over period include a 2021 gain on sale of assets of $63.9 million related to the Hawaii sale-leaseback transactions with no such gain in 2022 and a 14% increase in operating expenses compared to 2021.
 Adjusted EBITDA and Adjusted Net Income (Loss). For the year ended December 31, 2022, Adjusted EBITDA was $643.4 million compared to $125.6 million for the year ended December 31, 2021. The improvement was primarily related to favorable realized refined product crack spreads at all our refineries, partially offset by unfavorable purchased product and crude oil differentials and unfavorable FIFO adjustments, unfavorable inventory financing and environmental compliance costs, and higher operating expenses compared to 2021.
 For the year ended December 31, 2022, Adjusted Net Income was $474.7 million compared to an Adjusted Net Loss of $39.0 million for the year ended December 31, 2021. The change was primarily related to the same factors described above for the increase in Adjusted EBITDA.

 The following table summarizes our consolidated results of operations for the years ended December 31, 2023, 2022, and 2021 (in thousands). The following should be read in conjunction with our consolidated financial statements under Item 8 of this Annual Report on Form 10-K.

 2023
 2022
 2021

 $
 $
 $

 —
 —
 1,838

 (11,844)
 —
 —

 3,663

 9,003
 9,591

 (59)
 (169)

 7,551,949
 6,883,882
 4,717,708

 (7,619)

 (72,450)
 (68,288)
 (66,493)

 (19,182)
 (5,329)
 (8,144)

 —
 —
 2,032

 (53)
 (52)

 —
 —

 Total other expense, net
 (66,700)
 (73,004)
 (72,657)

 613,306
 364,899
 (80,276)

 Income tax benefit (expense)
 115,336
 (710)
 (1,021)

 $
 $
 $

 The following tables summarize our operating income (loss) by segment for the years ended December 31, 2023, 2022, and 2021 (in thousands). The following should be read in conjunction with our consolidated financial statements under Item 8 of this Annual Report on Form 10-K.

 Year ended December 31, 2023
 Logistics (1)
 Corporate, Eliminations and Other (2)
 Total

 $
 7,969,480
 $
 260,779
 $
 592,480
 $
 (590,784)
 $

 6,845,834
 145,944
 437,198
 (590,867)

 373,612
 24,450
 87,525
 —

 81,017
 25,122
 11,462
 2,229

 —
 —
 —

 (7,363)
 (4,481)
 —
 —
 (11,844)

 —
 —
 —

 —
 —
 —

 —
 (308)
 (59)

 $
 676,161
 $
 69,744
 $
 56,603
 $
 (122,502)
 $

 Year ended December 31, 2022
 Logistics (1)
 Corporate, Eliminations and Other (2)
 Total

 $
 7,046,060
 $
 198,821
 $
 570,206
 $
 (493,302)
 $

 6,332,694
 109,458
 428,712
 (494,850)

 236,989
 14,988
 81,229
 —

 65,472
 20,579
 10,971
 2,747

 —
 —
 —

 —
 —
 —
 3,663
 3,663

 9,003
 —
 —
 —
 9,003

 (253)
 (169)

 $
 401,901
 $
 54,049
 $
 49,238
 $
 (67,285)
 $

 Year ended December 31, 2021
 Logistics (1)
 Corporate, Eliminations and Other (2)
 Total

 $
 4,471,111
 $
 184,734
 $
 456,416
 $
 (402,172)
 $

 4,306,371
 96,828
 337,476
 (402,201)

 203,511
 14,722
 71,845
 —

 58,258
 22,044
 10,880
 3,059

 1,838
 —
 —
 —
 1,838

 —
 —
 —

 —
 —
 —

 9,591
 —
 —
 —
 9,591

 (19,659)
 (19)
 (45,034)

 $
 (88,799)
 $
 51,159
 $
 81,249
 $
 (51,228)
 $
 (7,619)

 (1)Our logistics operations consist primarily of intercompany transactions which eliminate on a consolidated basis.
 (2)Includes eliminations of intersegment Revenues and Cost of revenues (excluding depreciation) of $590.8 million, $493.3 million, and $402.2 million for the years ended December 31, 2023, 2022, and 2021, respectively.

 Below is a summary of key operating statistics for the refining segment for the years ended December 31, 2023, 2022, and 2021:

 2023
 2022
 2021

 Total Refining Segment

 Feedstocks Throughput (Mbpd) (1)

 170.3
 133.8
 135.2

 Refined product sales volume (Mbpd) (1)

 183.1
 140.3
 138.8

 Hawaii Refinery

 Feedstocks Throughput (Mbpd)
 80.8
 81.8
 82.0

 Yield (% of total throughput)

 Gasoline and gasoline blendstocks
 26.3
 %
 25.6
 %
 24.8
 %

 Distillates
 40.4
 %
 38.8
 %
 45.0
 %

 Fuel oils
 28.9
 %
 31.4
 %
 26.6
 %

 Other products
 1.1
 %
 0.7
 %
 0.6
 %

 Total yield
 96.7
 %
 96.5
 %
 97.0
 %

 Refined product sales volume (Mbpd)
 89.1
 84.0
 82.6

 Adjusted Gross Margin per bbl ($/throughput bbl) (2)

 $
 15.25
 $
 13.99
 $
 4.56

 Production costs per bbl ($/throughput bbl) (3)

 4.57
 4.86
 3.98

 D&A per bbl ($/throughput bbl)
 0.65
 0.67
 0.66

 Montana Refinery

 Feedstocks Throughput (Mbpd) (1)

 54.4
 —
 —

 Yield (% of total throughput)

 Gasoline and gasoline blendstocks
 48.1
 %
 —
 %
 —
 %

 Distillates
 32.0
 %
 —
 %
 —
 %

 Asphalt
 12.1
 %
 —
 %
 —
 %

 Other products
 3.2
 %
 —
 %
 —
 %

 Total yield
 95.4
 %
 —
 %
 —
 %

 Refined product sales volume (Mbpd)
 58.6
 —
 —

 Adjusted Gross Margin per bbl ($/throughput bbl) (2)

 $
 21.14
 $
 —
 $
 —

 Production costs per bbl ($/throughput bbl) (3)

 10.78
 —
 —

 D&A per bbl ($/throughput bbl)
 1.45
 —
 —

 Washington Refinery

 Feedstocks Throughput (Mbpd)
 40.0
 35.5
 36.3

 Yield (% of total throughput)

 Gasoline and gasoline blendstocks
 23.5
 %
 24.0
 %
 23.7
 %

 Distillates
 34.5
 %
 34.3
 %
 34.5
 %

 Asphalt
 19.7
 %
 20.3
 %
 20.7
 %

 Other products
 18.7
 %
 18.2
 %
 18.3
 %

 Total yield
 96.4
 %
 96.8
 %
 97.2
 %

 2023
 2022
 2021

 Refined product sales volume (Mbpd)
 41.7
 39.7
 39.6

 Adjusted Gross Margin per bbl ($/throughput bbl) (2)

 $
 9.41
 $
 18.00
 $
 2.98

 Production costs per bbl ($/throughput bbl) (3)

 4.12
 4.01
 3.86

 D&A per bbl ($/throughput bbl)
 1.91
 2.19
 1.57

 Wyoming Refinery

 Feedstocks Throughput (Mbpd)
 17.6
 16.5
 16.9

 Yield (% of total throughput)

 Gasoline and gasoline blendstocks
 47.1
 %
 49.7
 %
 47.3
 %

 Distillates
 46.7
 %
 43.1
 %
 45.7
 %

 Fuel oil
 2.5
 %
 2.4
 %
 2.2
 %

 Other products
 1.5
 %
 2.1
 %
 1.7
 %

 Total yield
 97.8
 %
 97.3
 %
 96.9
 %

 Refined product sales volume (Mbpd)
 17.9
 16.6
 16.6

 Adjusted Gross Margin per bbl ($/throughput bbl) (2)

 $
 25.15
 $
 26.50
 $
 14.47

 Production costs per bbl ($/throughput bbl) (3)

 7.50
 7.32
 6.22

 D&A per bbl ($/throughput bbl)
 2.69
 2.85
 2.86

 Market Indices (average $ per barrel)

 3-1-2 Singapore Crack Spread (4)

 $
 19.50
 $
 25.43
 $
 6.22

 RVO Adjusted Pacific Northwest 3-1-1-1 Index (5)

 25.82
 35.27
 13.69

 RVO Adjusted USGC 3-2-1 Index (6)

 22.87
 28.55
 10.98

 Crude Oil Prices (average $ per barrel)

 Brent
 $
 82.17
 $
 99.04
 $
 70.95

 WTI
 77.60
 94.33
 68.11

 ANS (7)

 82.36
 98.76
 70.56

 Bakken Clearbrook (7)

 78.58
 96.37
 67.65

 WCS Hardisty (7)

 59.34
 73.28
 53.90

 Brent M1-M3
 0.81
 3.49
 1.12

 (1)Feedstocks throughput and sales volumes per day for the Montana refinery for the year ended December 31, 2023 are calculated based on the 214-day period for which we owned the Montana refinery in 2023. As such, the amounts for the total refining segment represent the sum of the Hawaii, Washington, and Wyoming refineries' throughput or sales volumes averaged over the year ended December 31, 2023 plus the Montana refinery's throughput or sales volumes averaged over the period from June 1, 2023 to December 31, 2023. The 2022 and 2021 amounts for the total refining segment represent the sum of the Hawaii, Washington, and Wyoming refineries' throughput or sales volumes averaged over the year ended December 31, 2022 and 2021.
 (2)We calculate Adjusted Gross Margin per barrel by dividing Adjusted Gross Margin by total refining throughput. Adjusted Gross Margin for our Washington refinery is determined under the last-in, first-out ("LIFO") inventory costing method. Adjusted Gross Margin for our other refineries is determined under the first-in, first-out ("FIFO") inventory costing method. The definition of Adjusted Gross Margin was modified beginning with the financial results reported for periods in

 fiscal year 2022. We have recast Adjusted Gross Margin for prior periods when reported to conform to the modified presentation. Please see discussion of Adjusted Gross Margin below.
 (3)Management uses production costs per barrel to evaluate performance and compare efficiency to other companies in the industry. There are a variety of ways to calculate production costs per barrel; different companies within the industry calculate it in different ways. We calculate production costs per barrel by dividing all direct production costs, which include the costs to run the refineries including personnel costs, repair and maintenance costs, insurance, utilities, and other miscellaneous costs, by total refining throughput. Our production costs are included in Operating expense (excluding depreciation) on our consolidated statement of operations, which also includes costs related to our bulk marketing operations.
 (4)We believe the 3-1-2 Singapore Crack Spread (or three barrels of Brent crude oil converted into one barrel of gasoline and two barrels of distillates (diesel and jet fuel)) is the most representative market indicator for our operations in Hawaii.
 (5)We believe the RVO Adjusted Pacific Northwest 3-1-1-1 (or three barrels of WTI crude oil converted into one barrel of Pacific Northwest gasoline, one barrel of Pacific Northwest ULSD and one barrel of USGC VGO, less 100% of the RVO cost for gasoline and ULSD) is the most representative market indicator for our operations in Washington with improved historical correlations to our reported adjusted gross margin compared to prior reported indices.
 (6)We believe the RVO Adjusted USGC 3-2-1 (or three barrels of WTI crude oil converted into two barrels of USGC gasoline and one barrel of USGC ULSD, less 100% of the RVO cost) is the most representative market indicator for our operations in Montana and Wyoming with improved historical correlations to our reported adjusted gross margin compared to prior reported indices.
 (7)Crude pricing has been updated to reflect simple averages of outright prices during the relevant period.

 Below is a summary of key operating statistics for the retail segment for the years ended December 31, 2023, 2022, and 2021:

 2023
 2022
 2021

 Retail Segment

 Retail sales volumes (thousands of gallons)
 117,550
 105,456
 109,150

 Non-GAAP Performance Measures
 Management uses certain financial measures to evaluate our operating performance that are considered non-GAAP financial measures. These measures should not be considered in isolation or as substitutes or alternatives to their most directly comparable GAAP financial measures or any other measure of financial performance or liquidity presented in accordance with GAAP. These non-GAAP measures may not be comparable to similarly titled measures used by other companies since each company may define these terms differently.
 We believe Adjusted Gross Margin (as defined below) provides useful information to investors because it eliminates the gross impact of volatile commodity prices and adjusts for certain non-cash items and timing differences created by our inventory financing agreements and lower of cost and net realizable value adjustments to demonstrate the earnings potential of the business before other fixed and variable costs, which are reported separately in Operating expense (excluding depreciation) and Depreciation and amortization. Management uses Adjusted Gross Margin per barrel to evaluate operating performance and compare profitability to other companies in the industry and to industry benchmarks. We believe Adjusted Net Income (Loss) and Adjusted EBITDA (as defined below) are useful supplemental financial measures that allow investors to assess the financial performance of our assets without regard to financing methods, capital structure, or historical cost basis, the ability of our assets to generate cash to pay interest on our indebtedness, and our operating performance and return on invested capital as compared to other companies without regard to financing methods and capital structure.
 Beginning with financial results reported for periods in fiscal year 2023, Adjusted Gross Margin, Adjusted Net Income (Loss), and Adjusted EBITDA also exclude the mark-to-market losses (gains) associated with our net obligation related to the Washington Climate Commitment Act and Clean Fuel Standard, which became effective on January, 1, 2023.
 Beginning with financial results reported for periods in fiscal year 2023, Adjusted Net Income (loss) and Adjusted EBITDA also exclude the redevelopment and other costs for our Par West facility, which was shut down in 2020. This modification improves comparability between periods by excluding expenses incurred in connection with the strategic redevelopment of this non-operating facility. We have recast Adjusted Net Income (Loss) and Adjusted EBITDA for prior periods when reported to conform to the modified presentation.

 Beginning with financial results reported for the second quarter of 2023, Adjusted Gross Margin, Adjusted Net Income (Loss), and Adjusted EBITDA also exclude our portion of interest, taxes, and depreciation expense from our refining and logistics investments acquired on June 1, 2023, as part of the Billings Acquisition.
 Beginning with financial results reported for the fourth quarter of 2023, Adjusted Gross Margin, Adjusted Net Income (Loss), and Adjusted EBITDA excludes all hedge losses (gains) associated with our Washington ending inventory and LIFO layer increment impacts associated with our Washington inventory. In addition, we have modified our environmental obligation mark-to-market adjustment to include only the mark-to-market losses (gains) associated with our net RINs liability and net obligation associated with the Washington Climate Commitment Act ("Washington CCA") and Clean Fuel Standard. This modification was made as part of our change in how we estimate our environmental obligation liabilities.
 Beginning with financial results reported for the fourth quarter of 2023, Adjusted Net Income (loss) excludes unrealized interest rate derivative losses (gains) and all Laramie Energy related impacts with the exception of cash distributions. Please read Note 2—Summary of Significant Accounting Policies, Environmental Credits and Obligations section, for a discussion of the change in estimate.

 Adjusted Gross Margin
 Adjusted Gross Margin is defined as operating income (loss) excluding:
 • operating expense (excluding depreciation);
 • depreciation and amortization ("D&A");
 • Par's portion of interest, taxes, and depreciation expense from refining and logistics investments;
 • impairment expense;
 • loss (gain) on sale of assets, net;
 • inventory valuation adjustment (which adjusts for timing differences to reflect the economics of our inventory financing agreements, including lower of cost or net realizable value adjustments, the impact of the embedded derivative repurchase or terminal obligations, hedge losses (gains) associated with our Washington ending inventory and intermediation obligation, purchase price allocation adjustments, and LIFO layer increment and decrement impacts associated with our Washington inventory);
 • Environmental obligation mark-to-market adjustment (which represents the mark-to-market losses (gains) associated with our net RINs liability and our net obligation associated with the Washington Climate Commitment Act and Clean Fuel Standard); and
 • unrealized loss (gain) on derivatives.
 The following tables present a reconciliation of Adjusted Gross Margin to the most directly comparable GAAP financial measure, operating income (loss), on a historical basis, for selected segments, for the periods indicated (in thousands):

 Year ended December 31, 2023

 Operating income
 $
 676,161
 $
 69,744
 $
 56,603

 373,612
 24,450
 87,525

 81,017
 25,122
 11,462

 Par's portion of interest, taxes, and depreciation expense from refining and logistics investments

 1,586
 1,857
 —

 102,710
 —
 —

 (189,783)
 —
 —

 Unrealized gain on derivatives
 (50,511)
 —
 —

 —
 (308)

 Adjusted Gross Margin (1)
 $
 995,011
 $
 121,173
 $
 155,282

 Year ended December 31, 2022

 Operating income
 $
 401,901
 $
 54,049
 $
 49,238

 236,989
 14,988
 81,229

 65,472
 20,579
 10,971

 (15,712)
 —
 —

 105,760
 —
 —

 Unrealized loss on derivatives
 9,336
 —
 —

 9,003
 —
 —

 (253)

 Adjusted Gross Margin (1)
 $
 812,750
 $
 89,363
 $
 141,494

 Year ended December 31, 2021

 $
 (88,799)
 $
 51,159
 $
 81,249

 203,511
 14,722
 71,845

 58,258
 22,044
 10,880

 1,838
 —
 —

 31,841
 —
 —

 66,350
 —
 —

 Unrealized loss on derivatives
 1,517
 —
 —

 9,591
 —
 —

 (19,659)
 (19)
 (45,034)

 Adjusted Gross Margin (1)
 $
 264,448
 $
 87,906
 $
 118,940

 ________________________________________
 (1) For the years ended December 31, 2023 and 2022, there was no impairment expense.

 Adjusted Net Income (Loss) and Adjusted EBITDA
 Adjusted Net Income (Loss) is defined as Net income (loss) excluding:

 • inventory valuation adjustment (which adjusts for timing differences to reflect the economics of our inventory financing agreements, including lower of cost or net realizable value adjustments, the impact of the embedded derivative repurchase or terminal obligations, hedge losses (gains) associated with our Washington ending inventory and intermediation obligation, purchase price allocation adjustments, and LIFO layer increment and decrement impacts associated with our Washington inventory);
 • Environmental obligation mark-to-market adjustments (which represents the mark-to-market losses (gains) associated with our RINs and Washington CCA and Clean Fuel Standard);
 • unrealized (gain) loss on derivatives;
 • acquisition and integration costs;
 • redevelopment and other costs related to Par West;
 • debt extinguishment and commitment costs;
 • increase in (release of) tax valuation allowance and other deferred tax items;
 • changes in the value of contingent consideration and common stock warrants;
 • severance costs;
 •(gain) loss on sale of assets;
 • impairment expense;
 • impairment expense associated with our investment in Laramie Energy; and
 • Par's share of equity losses from Laramie Energy, LLC, excluding cash distributions.
 Adjusted EBITDA is defined as Adjusted Net Income (Loss) excluding:
 • D
 • interest expense and financing costs, net, excluding interest rate derivative loss (gain);

 • cash distributions from Laramie Energy, LLC to Par;
 • Par's portion of interest, taxes, and depreciation expense from refining and logistics investments; and
 • income tax expense (benefit) excluding the increase in (release of) tax valuation allowance.
 The following table presents a reconciliation of Adjusted Net Income (Loss) and Adjusted EBITDA to the most directly comparable GAAP financial measure, net income (loss), on a historical basis for the periods indicated (in thousands):

 2023
 2022
 2021

 $
 $
 $

 102,710
 (15,712)
 31,841

 (189,783)
 105,760
 66,350

 Unrealized loss (gain) on derivatives

 (49,690)
 9,336
 (1,393)

 —
 —

 3,663

 19,182
 5,329
 8,144

 Changes in valuation allowance and other deferred tax items (1)
 (126,219)
 —
 —

 Severance costs
 1,785
 2,272

 —
 —
 1,838

 Equity losses from Laramie Energy, LLC, excluding cash distributions

 (14,279)
 —
 —

 (59)
 (169)

 Adjusted Net Income (Loss) (2)
 501,168
 474,668
 (39,043)

 Interest expense and financing costs, net, excluding unrealized interest rate derivative loss (gain)

 71,629
 68,288
 69,403

 Laramie Energy, LLC cash distributions to Par
 (10,706)
 —
 —

 Par's portion of interest, taxes, and depreciation expense from refining and logistics investments
 3,443
 —
 —

 Income tax expense
 10,883
 1,021

 Adjusted EBITDA (2)

 $
 696,247
 $
 643,435
 $
 125,622

 (1)For the year ended December 31, 2023, recognized a non-cash deferred tax benefit of $126.2 million related to the release of a majority of the valuation allowance against our federal net deferred tax assets. This tax benefit is included in Income tax expense (benefit) on our consolidated statements of operations.
 (2)For the years ended December 31, 2022 and 2021, there was no change in value of contingent consideration, change in value of common stock warrants, impairments associated with our investment in Laramie Energy, or our share of Laramie Energy's asset impairment losses in excess of our basis difference. Please read the Non-GAAP Performance Measures discussion above for information regarding changes to the components of Adjusted Net Income (Loss) and Adjusted EBITDA made during 2023.

 Discussion of Operating Income by Segment
 Year Ended December 31, 2023 Compared to Year Ended December 31, 2022
 Refining. Operating income for our refining segment was $676.2 million for the year ended December 31, 2023, an improvement of $274.3 million compared to $401.9 million for the year ended December 31, 2022. The increase in operating income was primarily driven by:

 •
 a decrease of $140.0 million in environmental credit and related obligations costs across our refineries in our legacy portfolio driven by favorable mark-to-market adjustments and a gain on retirement of prior year RINs,

 •
 an increase of $106.0 million driven by a 6% increase in refined product sales volumes at our refineries in our legacy portfolio,

 •
 a favorable change in step-out obligations related to our intermediation agreements of $79.5 million driven by changes in commodity prices,

 •
 a net decrease of $76.4 million in our derivative costs associated with all our refineries,

 •
 a $56.9 million contribution from the Billings Acquisition,

 •
 $37.0 million related to lower fuel burn costs at all our refineries, and

 •
 an increase of $32.8 million related to a favorable change in crude oil differentials at our refineries in our legacy portfolio,

 partially offset by:

 •
 a net decrease of $112.9 million related to declining crack spreads at our refineries in our legacy portfolio,

 •
 an increase in purchased product costs of $98.0 million at all our refineries in our legacy portfolio, and

 •
 an increase in logistics and other product delivery costs of $35.6 million at our refineries in our legacy portfolio.

 Logistics. Operating income for our logistics segment was $69.7 million for the year ended December 31, 2023, an increase of $15.7 million compared to $54.0 million for the year ended December 31, 2022. The increase is primarily due to an $8.5 million contribution from the Billings Acquisition logistics assets acquired in June 2023 and an $10.4 million increase in operating income driven by an increase in throughput volumes throughout our legacy logistics portfolio, partially offset by an increase in variable expenses of $5.5 million.
 Retail. Operating income for our retail segment was $56.6 million for the year ended December 31, 2023, an increase of $7.4 million compared to operating income of $49.2 million for the year ended December 31, 2022. The increase in operating income was primarily driven by $10.6 million related to higher fuel sales volumes and $3.4 million associated with increased merchandise sales, partly offset by $6.3 million of higher operating expenses driven by increases in employee costs and credit card fees in the year ended December 31, 2023 compared to the year ended December 31, 2022.

 Year Ended December 31, 2022 Compared to Year Ended December 31, 2021
 Refining. Operating income for our refining segment was $401.9 million for the year ended December 31, 2022, an improvement of $490.7 million compared to an operating loss of $88.8 million for the year ended December 31, 2021. The increase in profitability was primarily driven by widening product crack spreads across all our refineries, and a favorable change in the valuation of the embedded derivatives related to our intermediation agreements driven by changes in commodity prices, partially offset by unfavorable purchased product and crude differentials, unfavorable FIFO adjustments, higher inventory financing costs of $79.0 million, increased fuel burn costs related to higher crude oil costs as discussed below, increased RINs costs of $54.7 million, and unfavorable derivative costs. Other factors impacting our results period over period include a 2021 gain on sale of assets of $19.7 million primarily related to the Sale-Leaseback Transactions we closed in the first quarter of 2021 and a 15% increase in operating expenses in 2022, primarily driven by increased utilities, maintenance, and employee costs.
 Logistics. Operating income for our logistics segment was $54.0 million for the year ended December 31, 2022, an increase of $2.8 million compared to operating income of $51.2 million for the year ended December 31, 2021. The increase is primarily due to higher third party revenues partially offset by net 2% and 4% decreased throughput across our Hawaii and Wyoming logistics assets, respectively.
 Retail. Operating income for our retail segment was $49.2 million for the year ended December 31, 2022, a decrease of $32.0 million compared to operating income of $81.2 million for the year ended December 31, 2021. The decrease in profitability was primarily due to a gain on sale of assets of $45.0 million primarily related to the 2021 Hawaii sale-leaseback transactions we closed in the first quarter of 2021 with no such gain in 2022 and a 13% increase in operating expenses in the year ended December 31, 2022 primarily related to increased employee costs, higher credit card processing fees due to increased gasoline prices, rebranding fees in Hawaii, and higher rent expense related to the additional leases from our 2021 Hawaii sale-leaseback transactions, partially offset by a 31% increase in fuel margin.

 Discussion of Adjusted Gross Margin by Segment
 Year Ended December 31, 2023 Compared to Year Ended December 31, 2022
 Refining. For the year ended December 31, 2023, our refining Adjusted Gross Margin was approximately $995.0 million, an increase of $182.2 million compared to $812.8 million for the year ended December 31, 2022. The increase in profitability was primarily due to Adjusted Gross Margin contributed by the Montana refinery of $246.1 million and 6.0% higher refined product sales margins across our legacy refining portfolio, partially offset by $155.6 million higher environmental credit obligation costs, excluding the mark-to-market impacts, and lower crack spreads of $107.6 million.
 • Adjusted Gross Margin for the Hawaii refinery improved by $1.26 per barrel from $13.99 per barrel during the year ended December 31, 2022, to $15.25 per barrel during the year ended December 31, 2023, primarily due to lower feedstock costs, a 6% increase in refined product sales volumes, a favorable change in realized derivatives, and higher yield, partially offset by $98.0 million higher purchased product costs and lower crack spreads. The Singapore 3-1-2 index declined from $25.43 in the year ended December 31, 2022 to $19.50 during the year ended December 31, 2023.
 • Adjusted Gross Margin for the Wyoming refinery decreased by $1.35 per barrel from $26.50 per barrel during the year ended December 31, 2022 to $25.15 per barrel during the year ended December 31, 2023. The change is primarily due to a 8% increase in refined product sales volumes, partially offset by lower crack spreads. The RVO Adjusted USGC 3-2-1 index declined from $28.55 during the year ended December 31, 2022 to $22.87 in the year ended December 31, 2023.
 • Adjusted Gross Margin for the Washington refinery decreased by $8.59 per barrel from $18.00 per barrel during the year ended December 31, 2022 to $9.41 per barrel during the year ended December 31, 2023, primarily due to higher environmental credit obligation expenses, declining crack spreads, and higher refined product delivery costs, partially offset by lower feedstock costs and 5% higher refined product sales volumes. The RVO Adjusted Pacific Northwest 3-1-1-1 index declined from $35.27 in the year ended December 31, 2022 to $25.82 during the year ended December 31, 2023.
 Logistics. For the year ended December 31, 2023, our logistics Adjusted Gross Margin was approximately $121.2 million, an increase of $31.8 million compared to $89.4 million for the year ended December 31, 2022. The increase was primarily due to Adjusted Gross Margin of $23.8 million contributed from the Billings Acquisition logistics assets acquired in June 2023 and a 3% increase in throughput across our legacy assets, net of associated higher fees and variable expenses, and higher third-party revenue.
 Retail. For the year ended December 31, 2023, our retail Adjusted Gross Margin was approximately $155.3 million, an increase of $13.8 million compared to $141.5 million for the year ended December 31, 2022. The increase was primarily related to an 11% increase in sales volumes and a 33% increase in merchandise sales.
 Year Ended December 31, 2022 Compared to Year Ended December 31, 2021
 Refining. For the year ended December 31, 2022, our refining Adjusted Gross Margin was approximately $812.8 million, an increase of $548.4 million compared to $264.4 million for the year ended December 31, 2021. The increase in profitability was primarily driven by favorable realized product crack spreads across all our refineries partially offset by unfavorable purchased product costs, unfavorable FIFO adjustments, increased inventory financing costs of $79.0 million in Hawaii, unfavorable derivative costs, and increased costs related to fuel burn related to higher crude oil costs as discussed below.
 • Adjusted Gross Margin for the Hawaii refinery improved from $4.56 per barrel in 2021 to $13.99 per barrel in 2022 primarily due to favorable product crack spreads, and a 1.7% increase in refined product sales volumes, partially offset by unfavorable purchased product and crude oil costs, unfavorable FIFO adjustments, a $78.8 million increase in intermediation fees driven primarily by $59.4 million higher market structure fees under the Supply and Offtake Agreement, increased fuel burn costs related to higher crude oil costs as discussed below, and unfavorable derivatives.
 • Adjusted Gross Margin for the Washington refinery increased by $15.02 per barrel primarily due to favorable product crack spreads, partially offset by unfavorable feedstock costs and increased costs related to fuel burn.
 • Adjusted Gross Margin for the Wyoming refinery increased by $12.03 per barrel primarily due to favorable product crack spreads, partially offset by unfavorable feedstock costs and increased RINs costs.

 Logistics. For the year ended December 31, 2022, our logistics Adjusted Gross Margin was approximately $89.4 million, an increase of $1.5 million compared to $87.9 million for the year ended December 31, 2021. The increase was

 primarily driven by higher third party revenues partially offset by net 2% and 4% decreased throughput across our Hawaii and Wyoming logistics assets, respectively.
 Retail. For the year ended December 31, 2022, our retail Adjusted Gross Margin was approximately $141.5 million, an increase of $22.6 million compared to $118.9 million for the year ended December 31, 2021. The increase was primarily due to a 31% increase in fuel margins partially offset by a 3% decline in sales volumes.

 Discussion of Consolidated Results
 Year Ended December 31, 2023 Compared to Year Ended December 31, 2022
 Revenues. For the year ended December 31, 2023, revenues were $8.2 billion, a $0.9 billion increase compared to $7.3 billion for the year ended December 31, 2022. The Billings Acquisition contributed revenues of $1.5 billion in the first seven months under our ownership, partially offset by a decrease of $0.6 billion across our legacy refinery portfolio. The decrease in our legacy refining revenue was primarily driven by a $0.8 billion decrease related to lower crude oil prices, partially offset by a 6% increase in sales volumes. Average Brent crude oil prices declined 17% and average WTI crude oil prices declined 18% as compared to the prior period. Revenues at our retail segment increased $22.3 million primarily due to an 11% increase in sales volume and a 33% increase in merchandise sales, partially offset by an 8% decrease in fuel sales prices.
 Cost of Revenues (Excluding Depreciation). For the year ended December 31, 2023, cost of revenues (excluding depreciation) was $6.8 billion, a $0.4 billion increase compared to $6.4 billion for the year ended December 31, 2022, inclusive of a $1.5 billion contribution from the Billings Acquisition. There was a decrease of $1.0 billion of cost of revenues (excluding depreciation) across our legacy refining operations primarily due to decreases in crude oil prices as discussed above.
 Operating Expense (Excluding Depreciation). For the year ended December 31, 2023, operating expense (excluding depreciation) was approximately $485.6 million, an increase of $152.4 million compared to $333.2 million for the year ended December 31, 2022. $134.1 million of the increase was contributed by the Billings Acquisition. Other factors that drove the increase include higher repair and maintenance and employee expenses.
 Depreciation and Amortization. For the year ended December 31, 2023, D&A expense was approximately $119.8 million, an increase of $20.0 million compared to $99.8 million for the year ended December 31, 2022. The increase was primarily driven by the $21.7 million contribution from the Billings Acquisition.
 General and Administrative Expense (Excluding Depreciation). For the year ended December 31, 2023, general and administrative expense (excluding depreciation) was approximately $91.4 million, an increase of $29.0 million compared to $62.4 million for the year ended December 31, 2022. The increase was primarily due to a $12.1 million increase in employee costs, a $6.0 million increase in outside services, $5.8 million of expenses related to development of our renewable projects, and $3.9 million higher IT expenses.
 Equity earnings from refining and logistics investments. For the year ended December 31, 2023, equity earnings from refining and logistics investments were $11.8 million. As part of the Billings Acquisition, we acquired a 65% limited partnership ownership interest in YELP and a 40% ownership interest in YPLC. For the year ended December 31, 2023, our proportionate share of YELP's net income and YPLC's net income was $8.1 million and $4.4 million, respectively. Please read Note 3—Refining and Logistics Equity Investments to our consolidated financial statements under Item 8 of this Form 10-K for additional information.
 Acquisition and Integration costs. For the year ended December 31, 2023, we incurred $17.5 million of acquisition and integration costs related to the Billings Acquisition, compared to $3.7 million of acquisition and integration costs for the year ended December 31, 2022. Please read Note 5—Acquisitions to our consolidated financial statements under Item 8 of this Form 10-K for more information.
 Par West redevelopment and other costs. For the year ended December 31, 2023, Par West redevelopment and other costs were $11.4 million, an increase of $2.4 million compared to $9.0 million for the year ended December 31, 2022, associated with the operation and decommissioning of our Par West facility.
 Interest Expense and Financing Costs, Net. For the year ended December 31, 2023, our interest expense and financing costs were approximately $72.5 million, an increase of $4.2 million compared to $68.3 million for the year ended December 31, 2022. The increase was primarily due to higher outstanding debt balances and increased borrowings under our inventory financing agreements. Please read Note 14—Debt and Note 12—Inventory Financing Agreements to our

 consolidated financial statements under Item 8 of this Form 10-K for further discussion on our indebtedness and inventory financing, respectively.
 Debt extinguishment and commitment costs. For the year ended December 31, 2023, our debt extinguishment and commitment costs were approximately $19.2 million in connection with the refinancing of our long-term debt in the first quarter of 2023 and the termination of the Washington Refinery Intermediation Agreement in the fourth quarter of 2023. For the year ended December 31, 2022, our debt extinguishment and commitment costs were approximately $5.3 million and primarily represented extinguishment costs associated with the repurchase and cancellation of an additional $36.9 million of 12.875% Senior Secured Notes in the second quarter of 2022. Please read Note 14—Debt to our consolidated financial statements under Item 8 of this Form 10-K for further discussion.
 Equity Earnings from Laramie Energy, LLC. For the year ended December 31, 2023, equity earnings from Laramie Energy, LLC were $25.0 million. On March 1, 2023, following a refinancing of certain debt, Laramie Energy, LLC was permitted to make a one-time cash distribution to its owners based on ownership percentage. Our share of this distribution was $10.7 million. Effective February 21, 2023, we resumed the application of equity method accounting with respect to our investment in Laramie Energy. In the fourth quarter of 2023 and due to Laramie Energy, LLC's positive financial results, our share of net income from our investment in Laramie Energy exceeded our share of net losses recorded during the period that equity method accounting was suspended and we recorded equity earnings of $14.3 million. There were no equity earnings from our investment in Laramie Energy, LLC, for the year ended December 31, 2022. Please read Note 4—Investment in Laramie Energy to our consolidated financial statements under Item 8 of this Form 10-K for more information.
 Income Taxes. For the year ended December 31, 2023, we recorded an income tax benefit of $115.3 million primarily related to the release of the federal tax valuation allowance in the fourth quarter of 2024, partially offset by deferred tax expense from net operating loss utilization and state tax expense. For the year ended December 31, 2022, we recorded an income tax expense of $0.7 million primarily driven by an increase in state taxable income. Please read Note 22—Income Taxes to our consolidated financial statements under Item 8 of this Form 10-K for more information.

 Year Ended December 31, 2022 Compared to Year Ended December 31, 2021
 Revenues. For the year ended December 31, 2022, revenues were $7.3 billion, a $2.6 billion increase compared to $4.7 billion for the year ended December 31, 2021. The increase was primarily the result of an increase of $2.5 billion in third-party revenues at our refining segment primarily as a result of increases in Brent and WTI crude oil prices. Brent crude oil prices rose to $99.04 per barrel for the year ended December 31, 2022 compared to $70.95 per barrel for the year ended December 31, 2021, and WTI crude oil prices averaged $94.33 per barrel during the year ended December 31, 2022 compared to $68.11 per barrel in the year ended December 31, 2021. Other factors contributing to the increase in revenues at our refining segment include improved realized product crack spreads across all our refineries. Revenues at our retail segment increased $113.8 million primarily due to a 36% increase in fuel prices slightly offset by a 3% decline in sales volume.
 Cost of Revenues (Excluding Depreciation). For the year ended December 31, 2022, cost of revenues (excluding depreciation) was $6.4 billion, a $2.1 billion increase compared to $4.3 billion for the year ended December 31, 2021. The increase was primarily due to increases in Brent and WTI crude oil prices as discussed above, unfavorable purchased products, higher feedstock costs, and higher inventory financing costs. These increases were partially offset by a favorable change in the valuation of the embedded derivatives related to our inventory financing agreements driven by changes in commodity prices.
 Operating Expense (Excluding Depreciation). For the year ended December 31, 2022, operating expense (excluding depreciation) was approximately $333.2 million, an increase of $43.1 million compared to $290.1 million for the year ended December 31, 2021. The increase was primarily due to higher utilities expenses, maintenance expenses at our Hawaii refinery and increased employee costs. Other factors contributing to the increase include higher outside services expenses.
 Depreciation and Amortization. For the year ended December 31, 2022, D&A expense was approximately $99.8 million, an increase of $5.6 million compared to $94.2 million for the year ended December 31, 2021. The increase was primarily due to amortization of our Washington refinery turnaround completed in 2022.
 Impairment Expense. During the year ended December 31, 2021, we recorded goodwill and asset impairment charges totaling $1.8 million primarily related to discontinued capital projects. Please read Note 9—Property, Plant, and Equipment and Impairment of Long-Lived Assets to our consolidated financial statements under Item 8 of this Form 10-K for further discussion on our 2021 asset impairment charges. There were no impairment charges during the year ended December 31, 2022.

 Gain on Sale of Assets, Net. For the year ended December 31, 2022, there was a $0.2 million gain on sale of assets, net, which resulted primarily from the sale of equipment. For the year ended December 31, 2021, the gain on sale of assets, net was approximately $64.7 million and primarily related to the gain recognized as a result of the Sale-Leaseback Transactions we closed in the first quarter of 2021. Please read Note 17—Leases to our consolidated financial statements under Item 8 of this Form 10-K for further discussion on the Sale-Leaseback Transactions.
 General and Administrative Expense (Excluding Depreciation). For the year ended December 31, 2022, general and administrative expense (excluding depreciation) was approximately $62.4 million, an increase of $14.3 million compared to $48.1 million for the year ended December 31, 2021. The increase was primarily due to higher employee costs and an increase in the use of outside services.
 Acquisition and Integration Costs. For the year ended December 31, 2022, we incurred approximately $3.7 million of acquisition and integration costs primarily related to costs incurred for the pending Billings Acquisition. For the year ended December 31, 2021, we incurred an immaterial amount of acquisition and integration costs. Please read Note 5—Acquisitions to our consolidated financial statements under Item 8 of this Form 10-K for more information.
 Interest Expense and Financing Costs, Net. For the year ended December 31, 2022, our interest expense and financing costs were approximately $68.3 million, an increase of $1.8 million compared to $66.5 million for the year ended December 31, 2021. The increase was primarily due to an increase of $7.4 million related to increased borrowings under our inventory financing agreements and increased rates on our Term Loan B Facility. These increases were partially offset by lower outstanding debt balances driven by the maturity of our outstanding 5.00% Convertible Senior Notes in June 2021, the repayment of the PHL, Mid Pac, and Retail Property Term Loans and interest rate swap related to the Retail Property Term Loan in the first quarter of 2021, and reduced interest on our 12.875% Senior Secured Notes driven by early repayment of these notes. Please read Note 12—Inventory Financing Agreements and Note 14—Debt to our consolidated financial statements under Item 8 of this Form 10-K for further discussion on our inventory financing and indebtedness, respectively.
 Debt extinguishment and commitment costs. For the year ended December 31, 2022, our debt extinguishment and commitment costs were approximately $5.3 million and primarily represented extinguishment costs associated with the repurchase and cancellation of an additional $36.9 million of 12.875% Senior Secured Notes in the second quarter of 2022. For the year ended December 31, 2021, our debt extinguishment and commitment costs were approximately primarily $8.1 million and primarily represented $6.6 million in extinguishment costs associated with the redemption of $36.8 million of 12.875% Senior Secured Notes in June 2021 and $1.4 million in extinguishment costs associated with the early repayment of the Retail Property Term Loan on February 23, 2021. Please read Note 14—Debt to our consolidated financial statements under Item 8 of this Form 10-K for further discussion.
 Gain on curtailment of pension obligation. During the year ended December 31, 2021, we recorded a gain on curtailment of pension obligation of $2.0 million related to the amendment to the Wyoming Refining defined benefit plan. Please read Note 20—Benefit Plans to our consolidated financial statements under Item 8 of this Form 10-K for further discussion on the gain on curtailment of pension obligation. There was no gain on curtailment of pension obligation for the year ended December 31, 2022.
 Income Taxes. For the year ended December 31, 2022, we recorded an income tax expense of $0.7 million primarily driven by an increase in state taxable income. For the year ended December 31, 2021, we recorded an income tax expense of $1.0 million primarily driven by foreign withholding taxes.

 Condensed Consolidating Financial Information
 On February 28, 2023, Par Petroleum, LLC ("Par Borrower") entered into the Term Loan Credit Agreement (the "Term Loan Credit Agreement") due 2030 with Wells Fargo Bank, National Association, as administrative agent, and the lenders party thereto. The Term Loan Credit Agreement was co-issued by Par Petroleum Finance Corp. (together with the Par Borrower, the "Term Loan Borrowers"), which has no independent assets or operations. The Term Loan Credit Agreement is guaranteed on a senior unsecured basis only as to payment of principal and interest by Par Pacific Holdings, Inc. (the "Parent") and is guaranteed on a senior secured basis by all of the subsidiaries of Par Borrower. The Term Loan Credit Agreement proceeds were used to refinance our existing Term Loan B and repurchase our outstanding 7.75% Senior Secured Notes and 12.875% Senior Secured Notes, all three of which had similar guarantees that were replaced by those on the Term Loan Credit Agreement.
 The following supplemental condensed consolidating financial information reflects (i) the Parent's separate accounts, (ii) Par Borrower and its consolidated subsidiaries' accounts (which are all guarantors of the Term Loan Credit Agreement), (iii) the accounts of subsidiaries of the Parent that are not guarantors of the Term Loan Credit Agreement and consolidating

 adjustments and eliminations, and (iv) the Parent's consolidated accounts for the dates and periods indicated. For purposes of the following condensed consolidating information, the Parent's investment in its subsidiaries is accounted for under the equity method of accounting (dollar amounts in thousands).

 As of December 31, 2023

 ASSETS

 Current assets

 Cash and cash equivalents
 $
 10,369
 $
 268,711
 $
 $
 279,107

 Restricted cash
 —
 —

 Trade accounts receivable
 —
 367,249
 —
 367,249

 —
 1,160,395
 —
 1,160,395

 4,767
 177,638
 —
 182,405

 Due from related parties
 380,159
 —
 (380,159)
 —

 Total current assets
 395,634
 1,973,993
 (380,132)
 1,989,495

 21,350
 1,552,496
 3,955
 1,577,801

 (16,487)
 (458,616)
 (3,310)
 (478,413)

 4,863
 1,093,880
 1,099,388

 Long-term assets

 Operating lease right-of-use ("ROU") assets
 7,005
 339,449
 —
 346,454

 Refining and logistics equity investments
 —
 —
 87,486
 87,486

 Investment in Laramie Energy, LLC
 —
 —
 14,279
 14,279

 Investment in subsidiaries
 1,070,518
 —
 (1,070,518)
 —

 Intangible assets, net
 —
 —

 —
 126,678
 2,597
 129,275

 65,323
 120,606
 186,655

 $
 1,478,746
 $
 3,610,241
 $
 (1,225,037)
 $

 LIABILITIES AND STOCKHOLDERS' EQUITY

 Current liabilities

 Current maturities of long-term debt
 $
 —
 $
 4,255
 $
 —
 $
 4,255

 —
 —

 Accounts payable
 4,991
 386,334
 —
 391,325

 Accrued taxes
 —
 40,064
 —
 40,064

 —
 72,833
 —
 72,833

 415,468
 5,347
 421,762

 Due to related parties
 128,922
 232,803
 (361,725)
 —

 Total current liabilities
 134,860
 1,746,119
 (356,378)
 1,524,601

 Long-term liabilities

 Long-term debt, net of current maturities
 —
 646,603
 —
 646,603

 Finance lease liabilities
 —
 16,693
 (4,255)
 12,438

 8,462
 274,055
 —
 282,517

 Other liabilities
 —
 119,618
 (57,251)
 62,367

 143,322
 2,803,088
 (417,884)
 2,528,526

 Commitments and contingencies

 Stockholders' equity

 Preferred stock
 —
 —
 —
 —

 Common stock
 —
 —

 Additional paid-in capital
 242,505
 (242,505)

 Accumulated earnings (deficit)
 558,581
 (558,581)

 Accumulated other comprehensive income (loss)
 8,174
 6,067
 (6,067)
 8,174

 Total stockholders' equity
 807,153
 (807,153)

 Total liabilities and stockholders' equity
 $
 1,478,746
 $
 3,610,241
 $
 (1,225,037)
 $

 As of December 31, 2022

 ASSETS

 Current assets

 Cash and cash equivalents
 $
 2,547
 $
 488,350
 $
 $
 490,925

 Restricted cash
 3,670
 —
 4,001

 Trade accounts receivable
 —
 252,816
 252,885

 —
 1,041,983
 —
 1,041,983

 2,229
 89,883
 (69)
 92,043

 Due from related parties
 229,431
 —
 (229,431)
 —

 Total current assets
 234,538
 1,876,702
 (229,403)
 1,881,837

 19,865
 1,200,747
 3,955
 1,224,567

 (14,967)
 (370,643)
 (3,123)
 (388,733)

 4,898
 830,104
 835,834

 Long-term assets

 Operating lease right-of-use ("ROU") assets
 2,649
 348,112
 —
 350,761

 Investment in subsidiaries
 487,943
 —
 (487,943)
 —

 Intangible assets, net
 —
 13,577
 —
 13,577

 —
 126,727
 2,598
 129,325

 72,721
 (4,131)
 69,313

 $
 730,751
 $
 3,267,943
 $
 (718,047)
 $

 LIABILITIES AND STOCKHOLDERS' EQUITY

 Current liabilities

 Current maturities of long-term debt
 $
 —
 $
 10,956
 $
 —
 $
 10,956

 —
 893,065
 —
 893,065

 Accounts payable
 4,176
 147,219
 —
 151,395

 Accrued taxes
 32,052
 —
 32,099

 65,294
 —
 66,081

 639,396
 640,494

 Due to related parties
 77,420
 118,139
 (195,559)
 —

 Total current liabilities
 82,941
 1,906,121
 (194,972)
 1,794,090

 Long-term liabilities

 Long-term debt, net of current maturities
 —
 494,576
 —
 494,576

 Finance lease liabilities
 —
 10,710
 (4,399)
 6,311

 3,273
 289,428
 —
 292,701

 Other liabilities
 —
 46,922
 1,510
 48,432

 86,214
 2,747,757
 (197,861)
 2,636,110

 Commitments and contingencies

 Stockholders' equity

 Preferred stock
 —
 —
 —
 —

 Common stock
 —
 —

 Additional paid-in capital
 409,686
 (409,686)

 Accumulated earnings (deficit)
 (200,687)
 104,479
 (104,479)
 (200,687)

 Accumulated other comprehensive income (loss)
 8,129
 6,021
 (6,021)
 8,129

 Total stockholders' equity
 520,186
 (520,186)

 Total liabilities and stockholders' equity
 $
 730,751
 $
 3,267,943
 $
 (718,047)
 $

 Year Ended December 31, 2023

 $
 —
 $
 8,231,886
 $
 $

 —
 —

 —
 —

 1,618
 118,024

 29,258
 62,189
 —

 —
 —
 (11,844)
 (11,844)

 —
 —

 —
 —

 (89)
 —
 (59)

 30,906
 7,532,699
 (11,656)
 7,551,949

 (30,906)
 699,187
 11,725

 (24)
 (72,789)
 (72,450)

 —
 (19,182)
 —
 (19,182)

 (97)
 —
 (53)

 Equity earnings (losses) from subsidiaries
 759,528
 —
 (759,528)
 —

 —
 —

 Total other income (expense), net
 759,548
 (92,068)
 (734,180)
 (66,700)

 607,119
 (722,455)
 613,306

 Income tax benefit (expense) (1)
 —
 (153,017)
 268,353
 115,336

 $
 $
 454,102
 $
 (454,102)
 $

 Adjusted EBITDA
 $
 (28,722)
 $
 709,613
 $
 15,356
 $
 696,247

 Year Ended December 31, 2022

 $
 —
 $
 7,321,656
 $
 $

 —
 6,377,494
 (1,480)

 —
 —

 2,131
 97,448

 17,882
 44,514
 —

 3,396
 —
 3,663

 —
 9,003
 —
 9,003

 (196)
 —
 (169)

 23,436
 6,861,736
 (1,290)
 6,883,882

 (23,436)
 459,920
 1,419

 (1)
 (68,655)
 (68,288)

 —
 (5,329)
 —
 (5,329)

 (20)
 (1)

 Equity earnings (losses) from subsidiaries
 388,008
 —
 (388,008)
 —

 Total other income (expense), net
 387,987
 (73,350)
 (387,641)
 (73,004)

 364,551
 386,570
 (386,222)
 364,899

 Income tax benefit (expense) (1)
 (362)
 (96,995)
 96,647
 (710)

 $
 $
 289,575
 $
 (289,575)
 $

 Adjusted EBITDA
 $
 (17,551)
 $
 659,378
 $
 1,608
 $
 643,435

 Year Ended December 31, 2021

 $
 —
 $
 4,710,039
 $
 $

 —
 —

 —
 290,795
 (717)

 2,452
 91,550

 —
 1,838
 —
 1,838

 12,435
 35,661
 —

 —
 —

 —
 9,591
 —
 9,591

 (10,949)
 (53,763)

 14,989
 4,756,960
 (54,241)
 4,717,708

 (14,989)
 (46,921)
 54,291
 (7,619)

 (2,600)
 (64,209)
 (66,493)

 —
 (6,728)
 (1,416)
 (8,144)

 —
 2,032
 —
 2,032

 (33)
 (19)
 —
 (52)

 Equity earnings (losses) from subsidiaries
 (63,649)
 —
 63,649
 —

 Total other income (expense), net
 (66,282)
 (68,924)
 62,549
 (72,657)

 (81,271)
 (115,845)
 116,840
 (80,276)

 Income tax benefit (expense) (1)
 (26)
 24,835
 (25,830)
 (1,021)

 $
 $
 (91,010)
 $
 91,010
 $

 Adjusted EBITDA
 $
 (12,468)
 $
 137,323
 $
 $
 125,622

 (1) The income tax benefit (expense) of the Parent Guarantor and Par Borrower and Subsidiaries is determined using the separate return method. The Non-Guarantor Subsidiaries and Eliminations column includes tax benefits recognized at the Par consolidated level that are primarily associated with changes to the consolidated valuation allowance and other deferred tax balances.

 Non-GAAP Financial Measures
 Adjusted EBITDA for the supplemental consolidating condensed financial information, which is segregated at the "Parent Guarantor," "Par Borrower and Subsidiaries," and "Non-Guarantor Subsidiaries and Eliminations" levels, is calculated in the same manner as for the Par Pacific Holdings, Inc. Adjusted EBITDA calculations. See "Results of Operations — Non-GAAP Performance Measures — Adjusted Net Income (Loss) and Adjusted EBITDA" above.
 The following tables present a reconciliation of Adjusted EBITDA to the most directly comparable GAAP financial measure, net income (loss), on a historical basis for the periods indicated (in thousands):

 Year Ended December 31, 2023

 $
 $
 454,102
 $
 (454,102)
 $

 —
 102,710
 —
 102,710

 —
 (189,783)
 —
 (189,783)

 Unrealized loss (gain) on derivatives
 —
 (49,690)
 —
 (49,690)

 —
 —

 —
 —

 —
 19,182
 —
 19,182

 Severance costs
 1,293
 —
 1,785

 Equity losses from Laramie Energy, LLC, excluding cash distributions
 —
 —
 (14,279)
 (14,279)

 (89)
 —
 (59)

 1,618
 118,024

 Interest expense and financing costs, net, excluding unrealized interest rate derivative loss (gain)

 71,968
 (363)
 71,629

 Laramie Energy, LLC cash distributions to Par
 —
 —
 (10,706)
 (10,706)

 Par's portion of interest, taxes, and depreciation expense from refining and logistics investments
 —
 —
 3,443
 3,443

 Equity losses (income) from subsidiaries
 (759,528)
 —
 759,528
 —

 Income tax expense (benefit)
 —
 153,017
 (268,353)
 (115,336)

 Adjusted EBITDA (1)

 $
 (28,722)
 $
 709,613
 $
 15,356
 $
 696,247

 Year Ended December 31, 2022

 $
 $
 289,575
 $
 (289,575)
 $

 —
 (15,712)
 —
 (15,712)

 —
 105,760
 —
 105,760

 Unrealized loss on derivatives
 —
 9,336
 —
 9,336

 3,396
 —
 3,663

 —
 5,329
 —
 5,329

 Severance costs
 1,921
 —
 2,272

 (196)
 —
 (169)

 2,131
 97,448

 Interest expense and financing costs, net, excluding unrealized interest rate derivative loss (gain)

 68,655
 (368)
 68,288

 Equity losses (income) from subsidiaries
 (388,008)
 —
 388,008
 —

 Income tax expense (benefit)
 96,995
 (96,647)

 Adjusted EBITDA (1)

 $
 (17,551)
 $
 659,378
 $
 1,608
 $
 643,435

 Year Ended December 31, 2021

 $
 $
 (91,010)
 $
 91,010
 $

 —
 31,841
 —
 31,841

 —
 66,350
 —
 66,350

 Unrealized gain on derivatives
 —
 (1,393)
 —
 (1,393)

 —
 —

 —
 6,728
 1,416
 8,144

 Severance costs
 —
 —

 —
 1,838
 —
 1,838

 (10,949)
 (53,763)

 2,452
 91,550

 Interest expense and financing costs, net, excluding unrealized interest rate derivative loss (gain)

 2,600
 67,119
 (316)
 69,403

 Equity losses (income) from subsidiaries
 63,649
 —
 (63,649)
 —

 Income tax expense (benefit)
 (24,835)
 25,830
 1,021

 Adjusted EBITDA (1)

 $
 (12,468)
 $
 137,323
 $
 $
 125,622

 (1)Please read the Non-GAAP Performance Measures and Adjusted Net Income (Loss) and Adjusted EBITDA discussions above for information regarding the components of Adjusted Net Income (Loss) and Adjusted EBITDA.

 Liquidity and Capital Resources
 Capital Resources and Available Liquidity
 Our liquidity and capital requirements are primarily a function of our debt maturities and debt service requirements and contractual obligations, capital expenditures, turnaround outlays, and working capital needs. Examples of working capital needs include purchases and sales of commodities and associated margin and collateral requirements, facility maintenance costs, and other costs such as payroll. Our primary sources of liquidity are cash flows from operations, cash on hand, amounts available under our credit agreements, and access to capital markets.

 Our liquidity position as of December 31, 2023 was $644.5 million that consisted of $279.1 million of cash and cash equivalents, $355.0 million of availability under the ABL Credit Facility, and $10.4 million of availability under the J. Aron Discretionary Draw Facility. In addition, we had the ability to issue letters of credit of up to $107 million under our LC Facility.
 As of December 31, 2023, we had access to the ABL Credit Facility, the LC Facility, the J. Aron Discretionary Draw Facility, and cash on hand of $279.1 million. In addition, we have the Supply and Offtake Agreement, which is used to finance the majority of the inventory at our Hawaii refinery. Generally, the primary uses of our capital resources have been in the operations of our refining and retail segments, for payments related to acquisitions, and to repay or refinance indebtedness.
 We believe our cash flows from operations and available capital resources will be sufficient to meet our current capital and turnaround expenditures, working capital, and debt service requirements for the next 12 months. We may seek to raise additional debt or equity capital to fund acquisitions and any other significant changes to our business or to refinance existing debt. We cannot offer any assurances that such capital will be available in sufficient amounts or at an acceptable cost.
 Significant Developments
 In the first quarter of 2021, we closed on the sale and leaseback of twenty-two (22) of our retail properties in Hawaii for an aggregate cash purchase price of approximately $112.8 million net of transaction fees (the "Sale-Leaseback Transactions"). We used approximately $53.1 million of the net cash proceeds to repay the certain financing arrangements which were related to certain of the retail properties and the remainder for general corporate purposes. Please read Note 17—Leases to our consolidated financial statements under Item 8 of this Form 10-K for additional discussion on the Sale-Leaseback Transactions.
 On March 19, 2021, we sold 5.75 million shares of common stock in an underwritten public offering at a public offering price of $16.00 per share, resulting in net proceeds of approximately $87.2 million (the "Equity Offering"), after deducting underwriting discounts and commissions and offering expenses. We used the net proceeds from the Equity Offering to repay the remaining $48.7 million in aggregate principal amount of 5.00% Convertible Senior Notes at maturity in June 2021 and $36.8 million in aggregate principal amount of 12.875% Senior Secured Notes, and the remainder for other general corporate purposes, including capital expenditures, and funding working capital. Please read Note 19—Stockholders' Equity to our consolidated financial statements under Item 8 of this Form 10-K for additional discussion on the Equity Offering.
 On April 26, 2023, we terminated the Prior ABL Credit Facility and entered into a new ABL Credit Facility. On June 1, 2023 we closed the Billings Acquisition; please read Note 5—Acquisitions to our consolidated financial statements under Item 8 of this Form 10-K for further information. On July 26, 2023, we entered into the July 2023 S&O Amendment in connection with a new LC Facility. On October 4, 2023, we entered into the Second Amendment to the ABL Credit Facility and terminated the Washington Refinery Intermediation Agreement.
 During the years ended December 31, 2023, 2022, and 2021, we had significant activity related to our inventory financing and debt agreements. Please read Note 12—Inventory Financing Agreements and Note 14—Debt to our consolidated financial statements under Item 8 of this Form 10-K for further discussion of significant activity related to our inventory financing and debt agreements, respectively.
 Other Sources of Liquidity
 We may from time to time seek to retire or purchase our common stock through cash purchases and/or exchanges for equity securities, in open market purchases, privately negotiated transactions, or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions, and other factors. The amounts involved may be material. On November 10, 2021, the Board authorized and approved a share repurchase program for up to $50 million of the currently outstanding shares of our common stock, with no specified end date. On August 2, 2023, the Board approved expanding the Company's share repurchase authorization from $50 million to $250 million. Please read Note 19—Stockholders' Equity to our consolidated financial statements under Item 8 of this Form 10-K for additional discussion on the share repurchase program. The Term Loan Credit Agreement may also require annual prepayments of principal with a variable percentage of our excess cash flow, 50% or 25% depending on our consolidated year end secured leverage ratio (as defined in the Term Loan Credit Agreement).

 Cash Flows
 The following table summarizes cash activities for the years ended December 31, 2023, 2022, and 2021 (in thousands):

 Years Ended December 31,

 2023
 2022
 2021

 Net cash provided by (used in) operating activities
 $
 579,156
 $
 452,606
 $
 (27,622)

 Net cash provided by (used in) investing activities
 (659,039)
 (87,308)
 74,628

 Net cash provided by (used in) financing activities
 (135,597)
 13,407
 (1,094)

 Cash flows for the year ended December 31, 2023
 Net cash provided by operating activities for the year ended December 31, 2023 was driven primarily by net income of $728.6 million, non-cash earnings from operations of approximately $53.2 million, and net cash used for changes in operating assets and liabilities of approximately $96.3 million. Non-cash earnings from operations consisted primarily of the following adjustments:

 •
 depreciation and amortization expenses of $119.8 million,

 •
 debt commitment and extinguishment costs of $19.2 million, and

 •
 stock based compensation costs of $11.6 million,

 •
 a benefit from deferred taxes of $126.3 million,

 •
 unrealized gain on derivatives contracts of $49.7 million,

 •
 a gain of $25.0 million from our equity investment in Laramie Energy, and

 •
 $11.8 million of non-cash equity earnings from our refining and logistics investments.

 Net cash used for changes in operating assets and liabilities resulted primarily from:

 •
 a decrease in gross environmental credit obligations primarily related to the settlement of our 2020, 2021, and 2022 RINs obligations, and

 •
 increase in prepaid and other primarily driven by a $65.5 million increase in Advances to suppliers for crude purchases.

 Net cash used in investing activities for the year ended December 31, 2023 consisted primarily of:

 •
 $595.4 million used for the Billings Acquisition, and

 •
 $82.3 million in additions to property, plant, and equipment driven by maintenance projects at our refineries and various profit improvement projects, including construction of a flagship retail store in Washington, improved crude processing equipment at our Hawaii refinery, a co-processing unit at our Tacoma refinery, and various IT infrastructure improvements,

 •
 a $10.7 million cash distribution received from Laramie Energy in the first quarter of 2023.

 Net cash used in financing activities was approximately $135.6 million for the year ended December 31, 2023 and consisted primarily of the following activities:

 •
 net repayments under the Discretionary Draw Facility and MLC receivable advances of $96.0 million,

 •
 aggregate payments of $23.1 million of deferred loan costs and debt extinguishment costs, related to our debt refinancing, and

 •
 repurchases of common stock of $67.8 million,

 •
 net borrowings of debt of $145.1 million primarily driven by the refinancing and consolidation of our debt.

 Cash flows for the year ended December 31, 2022
 Net cash provided by operating activities for the year ended December 31, 2022, was primarily driven by net income of approximately $364.2 million, non-cash charges to operations of approximately $127.6 million, and net cash used for changes in operating assets and liabilities of approximately $39.2 million. Non-cash charges to operations consisted primarily of the following adjustments:

 •
 depreciation and amortization expenses of $99.8 million,

 •
 stock based compensation costs of $9.4 million,

 •
 unrealized loss on derivatives contracts of $9.3 million, and

 •
 debt commitment and extinguishment costs of $5.3 million.

 Net cash used for changes in operating assets and liabilities resulted primarily from:

 •
 net increases in our Supply and Offtake Agreement and Washington Refinery Intermediation Agreement obligations and accounts payable, and

 •
 an increase in gross environmental credit obligations primarily related to current period production volumes and increases in RINs prices,

 •
 net increases in our inventories and accounts receivable resulting from higher crude oil and refined product prices and higher inventory volumes at our Hawaii refinery, and

 •
 increase in prepaid and other primarily driven by a $34.7 million increase in Collateral posted with broker for derivative instruments.

 Net cash used in investing activities for the year ended December 31, 2022 consisted primarily of:

 •
 $53.0 million in additions to property, plant, and equipment driven by profit improvement and turnaround projects including crude recovery and debottlenecking projects at our Tacoma refinery, maintenance and tank replacement projects at our Wyoming refinery, and co-generation engine and tank conversion projects at our Hawaii refinery, and

 •
 $35.5 million related to acquisitions, primarily comprised of a $30.0 million deposit on the Billings Acquisition and $5.5 million for a three-store expansion of our Washington retail footprint.

 Net cash provided by financing activities for the year ended December 31, 2022 was approximately $13.4 million and and consisted primarily of the following activities:

 •
 net borrowings under the J. Aron Discretionary Draw Facility and MLC receivable advances of $80.7 million,

 •
 net repayments of debt of $62.0 million primarily driven by the partial repurchase and cancellation of our 7.75% Senior Secured Notes and 12.875% Senior Secured Notes, and

 •
 repurchases of common stock of $7.8 million.

 Cash flows for the year ended December 31, 2021
 Net cash used in operating activities was approximately $27.6 million for the year ended December 31, 2021, which resulted from a net loss of approximately $81.3 million, partially offset by non-cash charges to operations of approximately $41.6 million and net cash provided by changes in operating assets and liabilities of approximately $12.1 million.
 Net cash provided by investing activities was approximately $74.6 million for the year ended December 31, 2021 and was primarily related to proceeds received from the Sale-Leaseback Transactions partially offset by additions to property, plant, and equipment totaling approximately $29.5 million.
 Net cash used in financing activities for the year ended December 31, 2021 was approximately $1.1 million and consisted primarily of proceeds of $87.2 million from our March 2021 equity offering of common stock partially offset by net repayments on our debt agreements, J. Aron deferred payment arrangement, and MLC receivable advances of $81.4 million and $5.6 million in extinguishment costs related to the repayment of the Retail Property Term Loan and a portion of the 12.875% Senior Secured Notes.

 Cash Requirements
 We have various cash requirements stemming from investment strategies, contractual obligations, and financial commitments in the normal course of our operations and financing activities. Contractual obligations include future cash payments required under existing contractual arrangements, such as debt and lease agreements. These cash requirements and obligations may result from both general financing activities and from commercial arrangements that are directly related to our operating activities. We also continue to seek strategic investments in business opportunities, however the amount and timing of those investments are not predictable. Our material cash requirements as of December 31, 2023 include:
 Debt and Interest Payments. Current and long-term debt includes the scheduled principal payments related to our outstanding debt obligations and ABL Credit Facility. Our estimated interest payments due for 2024 are $51.2 million and our total estimated undiscounted future interest payments will be $312.4 million on the debt obligations held as of December 31, 2023 and using interest rates in effect as of December 31, 2023. Please read Note 14—Debt to our consolidated financial statements under Item 8 of this Form 10-K for further discussion.
 Debt Refinancing. On February 28, 2023, we entered into the Term Loan Credit Agreement. The proceeds were used to repurchase and cancel the then-outstanding 7.75% Senior Secured Notes and 12.875% Senior Secured Notes and terminate and repay all amounts outstanding under the Term Loan B Facility. As a result of this refinancing, our debt maturity was extended from 2026 to 2030 and, using interest rates that were in effect at December 31, 2023, our estimated undiscounted future interest payments increased to $310 million. On April 26, 2023, we terminated the prior ABL Credit Facility and entered into a new ABL Credit Facility. On October 4, 2023, we terminated the Washington Refinery Intermediation Agreement in connection with the Second Amendment to the ABL Credit Facility that increased the borrowing base. Please read Note 14—Debt to our consolidated financial statements under Item 8 of this Form 10-K for further discussion.
 Capital Expenditures and Turnaround Costs. Our deferred turnaround costs and capital expenditures, including land and building purchases but excluding acquisitions, for the year ended December 31, 2023, totaled approximately $88.1 million and were primarily related to the 2023 turnaround and related scheduled maintenance work at our Montana refinery, capital projects at our Hawaii and Tacoma refineries, land purchases and new sites at our Retail and Hawaii Logistics businesses, and sustaining maintenance at each of our refineries. Our capital expenditures and deferred turnaround costs budget for 2024 is approximately $220 to $250 million and primarily relates to scheduled maintenance, capital projects, and turnaround projects related to regulatory compliance, information technology, and growth across each of our businesses.
 Operating Lease Liabilities. Operating lease liabilities primarily include obligations associated with the lease of land, office space, retail facilities, and other facilities used in the storage and transportation of crude oil and refined products. Please read Note 17—Leases to our consolidated financial statements under Item 8 of this Form 10-K for further discussion.

 Finance Lease Liabilities. Finance lease liabilities primarily include obligations associated with the lease of retail facilities and vehicles. Please read Note 17—Leases to our consolidated financial statements under Item 8 of this Form 10-K for further discussion.
 Purchase Commitments. Purchase commitments primarily consist of contracts executed as of December 31, 2023 for the purchase of crude oil for use at our refineries that are scheduled for delivery in 2024. As of December 31, 2023, we have material purchase commitments of $1.3 billion, with required cash outlays primarily expected in the next twelve months.
 Supply and Offtake Agreement. On June 1, 2021, we and J. Aron entered into the second amended and restated supply and offtake agreement which expires on May 31, 2024. We and J. Aron entered into amendments to the Supply and Offtake Agreement on April 25, 2022, and May 17, 2022, which, among other things, increased the capacity under the Discretionary Draw Facility. On July 26, 2023, we entered into the July 2023 S&O Amendment to the Supply and Offtake Agreement which, among other things, allowed PHR to enter into a crude oil procurement contract supported by a letter of credit under the LC Facility and have its purchases funded by J. Aron, subject to certain conditions. Please read Note 12—Inventory Financing Agreements to our consolidated financial statements under Item 8 of this Form 10-K for more information.
 LC Facility. On July 26, 2023, we entered into an LC Facility intended to finance and provide credit support for certain of PHR's purchases of crude oil. In addition, revolving credit loans may be used to pay suppliers. The amount available is $120.0 million with the right to request an increase up to $350.0 million in the aggregate, subject to certain conditions. Please read Note 12—Inventory Financing Agreements to our consolidated financial statements under Item 8 of this Form 10-K for more information.
 Environmental Matters. Our operations are subject to extensive and periodically-changing federal, state, and local environmental laws and regulations including but not limited to air emissions, wastewater discharges, and solid and hazardous waste management activities. Additionally, we have asset retirement obligations in the period in which we have a legal obligation, whether by government or regulatory action or contractual arrangement, to incur these costs and can make a reasonable estimate of the fair value of the liability. Please read Note 10—Asset Retirement Obligations and Note 18—Commitments and Contingencies to our consolidated financial statements under Item 8 of this Form 10-K for more information.

 Critical Accounting Estimates
 The discussion and analysis of our financial condition and results of operations were based on the consolidated financial statements, which have been prepared in accordance with U.S. GAAP. The preparation of these consolidated financial statements required us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues, and expenses. Our significant accounting policies are described in our audited consolidated financial statements under Item 8 of this Form 10-K. We have identified certain estimates as being of particular importance to the portrayal of our financial position and results of operations and which require the application of significant judgment by management. We analyze our estimates on a periodic basis, including those related to fair value, impairments, natural gas and crude oil reserves, bad debts, natural gas and oil properties, income taxes, derivatives, contingencies, and litigation and base our estimates on historical experience and various other assumptions that we believe are reasonable under the circumstances. Actual results may differ from these estimates under different assumptions or conditions.
 Inventory and Obligations Under Inventory Financing Agreements
 Commodity inventories, excluding commodity inventories at the Washington refinery, are stated at the lower of cost and net realizable value using the FIFO accounting method. Commodity inventories at the Washington refinery are stated at the lower of cost and net realizable value using the LIFO inventory accounting method. We value merchandise along with spare parts, materials, and supplies at weighted average cost. Estimating the net realizable value of our inventory requires management to make assumptions about the timing of sales and the expected proceeds that will be realized for these sales. Please read Note 7—Inventories to our consolidated financial statements under Item 8 of this Form 10-K for additional information.
 A portion of the crude oil utilized at the Hawaii refinery is financed by J. Aron under procurement contracts. The crude oil remains in the legal title of J. Aron and is stored in our storage tanks governed by a storage agreement. Legal title to the crude oil passes to us at the tank outlet. After processing, J. Aron takes title to the refined products stored in our storage tanks until they are sold to our retail locations or to third parties. We record the inventory owned by J. Aron on our behalf as inventory with a corresponding accrued liability on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties and we have an obligation to repurchase it. The valuation of our repurchase obligation requires that we make estimates of the prices and differentials assuming settlement occurs at the end of the reporting period.

 On July 26, 2023, we entered into an LC Facility, intended to finance and provide credit support for certain of PHR's purchases of crude oil. In addition, revolving credit loans may be used to pay suppliers. The amount available is $120.0 million with the right to request an increase up to $350.0 million in the aggregate, subject to certain conditions.
 Please read Note 12—Inventory Financing Agreements to our consolidated financial statements under Item 8 of this Form 10-K for additional information regarding our Hawaii inventory financing agreement and LC Facility.
 Fair Value Measurements
 We measure certain assets and liabilities at their fair market value. Assets and liabilities measured at fair value on a recurring basis include derivative instruments and environmental credit obligations. We also measure certain assets and liabilities at fair value on a nonrecurring basis when specific triggering events occur, such as business combinations and events which indicate that a reporting unit's carrying value exceeds its estimated fair value. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. In estimating fair value, we use discounted cash flow projections, recent comparable market transactions, if available, or quoted prices. We consider assumptions that third parties would make in estimating fair value, including the highest and best use of the asset. The assumptions used by another party could differ significantly from our assumptions.
 We classify fair value balances based on the classification of the inputs used to calculate the fair value of a transaction. The inputs used to measure fair value have been placed in a hierarchy based on priority. The hierarchy gives the highest priority to unadjusted, readily observable quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Please read Note 16—Fair Value Measurements to our consolidated financial statements under Item 8 of this Form 10-K for additional information.
 Business Combinations
 We recognize assets acquired and liabilities assumed in business combinations separately from goodwill at their estimated fair values as of the date of acquisition. Significant judgment is required in estimating the fair value of assets acquired. We obtain the assistance of third-party valuation specialists in estimating fair values of tangible and intangible assets based on available historical information and on expectations and assumptions about the future, considering the perspectives of marketplace participants. These valuation methods require management to make estimates and assumptions regarding characteristics of the acquired property and future revenues and expenses. Changes in these estimates and assumptions would result in different amounts allocated to the related assets and liabilities. The measurement period may be up to one year from the acquisition date; we may record adjustments to the preliminary purchase price allocation during this time, concluding at the end of the one year period or final determination of the values of consideration transferred and assets and liabilities assumed, whichever comes first. Subsequent adjustments, if any, are recorded to the consolidated statement of operations. Please read Note 5—Acquisitions and Note 16—Fair Value Measurements to our consolidated financial statements under Item 8 of this Form 10-K for further information.
 Impairment of Goodwill and Long-lived Assets
 We assess the recoverability of the carrying value of goodwill during the fourth quarter of each year or whenever events or changes in circumstances indicate that the carrying amount of the goodwill of a reporting unit may not be fully recoverable. We first assess qualitative factors to determine whether it is more likely than not that the fair value of the reporting unit is less than its carrying value. If the qualitative assessment indicates that it is more likely than not that the carrying value of a reporting unit exceeds its estimated fair value, a quantitative test is required. Under the quantitative test, we compare the carrying value of the net assets of the reporting unit to the estimated fair value of the reporting unit. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment loss is recorded. The fair value of a reporting unit is determined using the income approach and the market approach. Under the income approach, we estimate the present value of expected future cash flows using a market participant discount rate. Under the market approach, we estimate fair value using observable multiples for comparable companies within our industry. These valuation methods require us to make significant estimates and assumptions regarding future cash flows, capital projects, commodity prices, long-term growth rates, and discount rates. Please read Note 11—Goodwill and Intangible Assets to our consolidated financial statements under Item 8 of this Form 10-K for further information.
 We review property, plant, and equipment, operating leases, and other long-lived assets whenever events or changes in business circumstances indicate the carrying value of the assets may not be recoverable. We use a cash flows model to estimate value because there is usually a lack of quoted market prices available for long-lived assets. Future cash flow estimates used for impairment reviews are based on assessments requiring judgment, including future production volumes, commodity prices, operating costs, margins, discount rates, expected capital expenditures, and other factors based on all available information

 available as of the date of the review. Impairment is required when the undiscounted cash flows estimated to be generated by those assets are less than the assets' carrying value. If this occurs, an impairment loss is recognized for the difference between the fair value and carrying value. The fair value of long-lived assets is determined using the income approach. Please read Note 9—Property, Plant, and Equipment and Impairment of Long-Lived Assets to our consolidated financial statements under Item 8 of this Form 10-K for further information.
 Environmental Matters and Asset Retirement Obligations
 We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed, and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Usually, the timing of these accruals coincides with the completion of a feasibility study or our commitment to a formal plan of action. Please read Note 18—Commitments and Contingencies to our consolidated financial statements under Item 8 of this Form 10-K for further information about our environmental liabilities and assessments.
 We record asset retirement obligations ("AROs") at fair value in the period in which we have a legal obligation, whether by government action or contractual arrangement, to incur these costs and can make a reasonable estimate of the fair value of the liability. Estimating the cost and timing of future remedial efforts is difficult and related technologies, costs, regulatory and other compliance considerations, timing, discount rates, and other inputs considered in the valuations are subject to change. Please read Note 2—Summary of Significant Accounting Policies, "Asset Retirement Obligations," to our consolidated financial statements under Item 8 of this Form 10-K for further information.
 Income Taxes
 We use the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and NOL and tax credit carry forwards. The realizability of deferred tax assets is evaluated quarterly based on a "more likely than not" standard and, to the extent this threshold is not met, a valuation allowance is recorded. In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. These liabilities are recorded based on our assessment of existing tax laws and regulations. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which these temporary differences become deductible and may vary from our estimates for a number of reasons, including different interpretations of tax laws and regulations. New tax laws and regulations, and changes to existing tax laws and regulations, are proposed and promulgated continuously. The implementation of future tax laws and regulatory initiatives, as well as future interpretations on historical tax laws and regulations, could result in increased tax liabilities that cannot be predicted at this time. Please read Note 2—Summary of Significant Accounting Policies, "Income Taxes," to our consolidated financial statements under Item 8 of this Form 10-K for further information.
 In the fourth quarter of 2023, we analyzed projections for our future taxable income and the absence of objective negative evidence, such as a cumulative loss in recent years. As a result of this analysis, we determined that we have sufficient positive evidence to release a majority of the valuation allowance against our federal net deferred tax assets and recognized a non-cash deferred tax benefit of $277.7 million for the year ended December 31, 2023. We retain a partial valuation allowance on certain state deferred tax assets primarily as a result of apportionment factors from minimal activity in certain states impacting assessed likelihood of future realizability. We will continue to reassess whether the balance of the valuation allowance is appropriate on a quarterly basis and, given the totality of the facts and circumstances, both positive and negative, will adjust the remaining valuation allowance in future periods if the evidence supports doing so.

 Item 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
 Commodity Price Risk
 Our earnings, cash flows, and liquidity are significantly affected by commodity price volatility. Our Revenues fluctuate with refined product prices and our Cost of revenues (excluding depreciation) fluctuates with movements in crude oil and feedstock prices. Assuming all other factors remain constant, a $1 per barrel change in average gross refining margins, based on our throughput of 170 Mbpd for the full year of 2023, would change annualized operating income by approximately $61.3 million. This analysis may differ from actual results.

 We utilize exchange-traded futures, options, and over-the-counter ("OTC") swaps to manage commodity price risks associated with:
 • the price for which we sell our refined products;
 • the price we pay for crude oil and other feedstocks;
 • our crude oil and refined products inventory; and
 • our fuel requirements for our refineries.
 Substantially all of our futures and OTC swaps are executed to economically hedge our physical commodity purchases, sales, and inventory. Our open futures and OTC swaps will expire in March 2025.
 Based on our net open futures positions at December 31, 2023, a $1 change in the price of crude oil, assuming all other factors remain constant, would result in $6.1 million change to the fair value of our derivative instruments and Cost of revenues (excluding depreciation).
 Our predominant variable operating cost is the cost of fuel consumed in the refining process, which is included in Cost of revenues (excluding depreciation) on our consolidated statements of operations. For the year ended December 31, 2023, we consumed approximately 170 Mbpd of crude oil during the refining process across all our refineries. We internally consumed approximately 4% of this throughput in the refining process, which is accounted for as a fuel cost. We have executed option collars to economically hedge our internally consumed fuel cost at all our refineries. Please read Note 15—Derivatives to our consolidated financial statements under Item 8 of this Form 10-K for more information.
 Compliance Program Price Risk
 We are exposed to market risks related to the volatility in the price of RINs required to comply with the Renewable Fuel Standard. Our renewable volume obligation ("RVO") is based on a percentage of our Hawaii, Wyoming, Washington and Montanta refineries' production of on-road transportation fuel. The EPA sets the RVO percentages annually. On June 3, 2022, the EPA finalized the 2021 and 2022 RVOs, reduced the existing 2020 RVO, denied 69 small refinery exemption petitions including ours, and proposed that certain small refineries be permitted to use an alternative RIN retirement schedule for their 2019-2020 compliance obligations. On June 21, 2023, the EPA finalized the 2023, 2024, and 2025 RVOs. To the degree we are unable to blend the required amount of biofuels to satisfy our RVO, we must purchase RINs on the open market. To mitigate the impact of this risk on our results of operations and cash flows, we may purchase RINs when the price of these instruments is deemed favorable. Some of these contracts are derivative instruments, however, we elect the normal purchases normal sales exception and do not record these contracts at their fair values.
 Additionally, we are exposed to market risks related to the volatility in the price of compliance credits required to comply with the Washington Climate Commitment Act and Clean Fuel Standard. To the extent we are unable to reduce the amount of greenhouse gas emissions in the transportation fuels we sell in Washington, we must purchase compliance credits at auction or in the open market. The number of credits required to comply with the Washington Climate Commitment Act and Clean Fuel Standard is based on the amount of greenhouse gas emissions in the transportation fuels we sell in Washington compared to certain regulatory limits. To mitigate the impact of this risk on our results of operations and cash flows, we may purchase credits when we deem the price to be favorable. Some of these contracts may be derivative instruments and recorded at their fair value. Please read Note 15—Derivatives to our consolidated financial statements under Item 8 of this Form 10-K for more information.
 Interest Rate Risk
 As of December 31, 2023, we had $665.6 million of indebtedness that was subject to floating interest rates. We also had interest rate exposure in connection with our liabilities under the J. Aron Supply and Offtake Agreement for which we pay charges based on three-month Secured Overnight Financing Rate ("SOFR"). An increase of 1% in the variable rate on our indebtedness, after considering the instruments subject to minimum interest rates, would result in an increase to our Cost of revenues (excluding depreciation) and Interest expense and financing costs, net of approximately $0.6 million and $7.3 million per year, respectively.
 We may utilize interest rate swaps to manage our interest rate risk. As of December 31, 2023 we had entered into an interest rate collar at a cap of 5.50% and floor of 2.30%, based on the three month SOFR as of the fixing date. This swap expires on May 31, 2026. Please read Note 15—Derivatives for more information.

 Credit Risk
 We are subject to the risk of loss resulting from nonpayment or nonperformance by our counterparties. We will continue to closely monitor the creditworthiness of customers to whom we grant credit and establish credit limits in accordance with our credit policy.

 Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
 The consolidated financial statements and schedule required by this item are set forth beginning on page F-1.

 Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURES
 None.

 Item 9A. CONTROLS AND PROCEDURES
 Evaluation of Disclosure Controls and Procedures
 Disclosure controls and procedures are designed with the objective of ensuring that all information required to be disclosed in our reports filed under the Securities Exchange Act of 1934, as amended ("Exchange Act"), such as this report, is recorded, processed, summarized, and reported within the time periods specified by the SEC. In connection with the preparation of this Annual Report on Form 10-K, as of December 31, 2023, an evaluation was performed under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act). Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that these disclosure controls and procedures were effective as of December 31, 2023. As previously disclosed, we completed the Billings Acquisition on June 1, 2023 and, as permitted by SEC guidance for newly acquired businesses, we have elected to exclude the acquired business operations from the scope of design and operation of our disclosure controls, and procedures for the year ended December 31, 2023.
 Changes in Internal Control over Financial Reporting
 Other than those changes made in connection with the Billings Acquisition on June 1, 2023, there were no changes during the year ended December 31, 2023, in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. The Billings Acquisition accounted for approximately 20% of total assets as of December 31, 2023 and approximately 19% of revenues of the Company for the year ended on December 31, 2023. We are currently in the process of integrating the Billings refinery operations, control processes and information systems into our systems and control environment and expect to include them in scope of design and operation of our internal control over financial reporting for the year ending December 31, 2024. We believe that we have taken the necessary steps to monitor and maintain appropriate internal control over financial reporting during this integration.

 MANAGEMENT'S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

 The Company's management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934). The Company's internal control system was designed to provide reasonable assurance to the Company's management and Board of Directors regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

 Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

 The Company's management assessed the effectiveness of the Company's internal control over financial reporting as of December 31, 2023. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control—Integrated Framework (2013). Based on such assessment, the Company's management concluded that, as of December 31, 2023, the Company's internal control over financial reporting was effective based on those criteria. As previously disclosed, we completed the Billings Acquisition on June 1, 2023, and, as permitted by SEC guidance for newly acquired businesses, we have elected to exclude the acquired business operations from the scope of design and operation of our disclosure controls, and procedures for the year ended December 31, 2023.

 Deloitte & Touche LLP, the Company's independent registered public accounting firm that audited the Company's financial statements included in this Annual Report on Form 10-K, has issued an audit report on the effectiveness of the Company's internal control over financial reporting as of December 31, 2023, which is included herein.

 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 To the shareholders and the Board of Directors of Par Pacific Holdings, Inc.

 Opinion on Internal Control over Financial Reporting
 We have audited the internal control over financial reporting of Par Pacific Holdings, Inc. and subsidiaries (the "Company") as of December 31, 2023, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control — Integrated Framework (2013) issued by COSO.
 We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements as of and for the year ended December 31, 2023, of the Company and our report dated February 29, 2024, expressed an unqualified opinion on those financial statements.
 As described in Management's Report on Internal Control Over Financial Reporting, management excluded from its assessment the internal control over financial reporting at the Billings Acquisition, which was acquired on June 1, 2023, and whose financial statements constitute 20 % and 19 % of total assets and revenue, respectively, of the consolidated financial statement amounts as of and for the year ended December 31, 2023. Accordingly, our audit did not include the internal control over financial reporting at the Billings Acquisition.

 Basis for Opinion
 The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company's internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
 We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

 Definition and Limitations of Internal Control over Financial Reporting
 A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.
 Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

 /s/ Deloitte & Touche LLP
 Houston, Texas
 February 29, 2024

 Item 9B. OTHER INFORMATION
 Rule 10b5-1 and Non-Rule 10b5-1 Trading Arrangements
 During the fiscal quarter ended December 31, 2023, no director or officer (as defined in Rule 16a-1(f) of the Securities Exchange Act) of the Company adopted or terminated any Rule 10b5-1 trading arrangements or non-Rule 105-1 trading arrangements as each term is defined in Item 408(a) of Regulation S-K.

 Item 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
 None.

 Item 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE
 The information required by this item is incorporated in this Annual Report on Form 10-K by reference to our definitive proxy statement or an amendment to this Annual Report on Form 10-K to be filed with the Securities and Exchange Commission not later than 120 days after the end of the fiscal year ended December 31, 2023.

 Item 11. EXECUTIVE COMPENSATION
 The information required by this item is incorporated in this Annual Report on Form 10-K by reference to our definitive proxy statement or an amendment to this Annual Report on Form 10-K to be filed with the Securities and Exchange Commission not later than 120 days after the end of the fiscal year ended December 31, 2023.

 Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
 The information required by this item is incorporated in this Annual Report on Form 10-K by reference to our definitive proxy statement or an amendment to this Annual Report on Form 10-K to be filed with the Securities and Exchange Commission not later than 120 days after the close of our fiscal year ended December 31, 2023.

 Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE
 The information required by this item is incorporated in this Annual Report on Form 10-K by reference to our definitive proxy statement or an amendment to this Annual Report on Form 10-K to be filed with the Securities and Exchange Commission not later than 120 days after the end of the fiscal year ended December 31, 2023.

 Item 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
 The information required by this item is incorporated in this Annual Report on Form 10-K by reference to our definitive proxy statement or an amendment to this Annual Report on Form 10-K to be filed with the Securities and Exchange Commission not later than 120 days after the end of the fiscal year ended December 31, 2023.

 Item 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

 (a)
 The following documents are filed as part of this report:

 (1)
 Consolidated Financial Statements (Included under Item 8). The Index to the Consolidated Financial Statements is included on page F- 1 of this Annual Report on Form 10-K and is incorporated herein by reference.

 (2)
 Financial Statement Schedules

 Schedule I – Condensed Financial Information of Registrant

 2.1
 Third Amended Joint Chapter 11 Plan of Reorganization of Delta Petroleum Corporation and Its Debtor Affiliates dated August 16, 2012. Incorporated by reference to Exhibit 2.1 to the Company's Current Report on Form 8-K filed on September 7, 2012.

 2.2
 Membership Interest Purchase Agreement dated as of June 17, 2013, by and among Tesoro Corporation, Tesoro Hawaii, LLC, and Hawaii Pacific Energy, LLC. Incorporated by reference to Exhibit 2.4 to the Company's Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2013, filed on August 14, 2013.

 2.3
 Agreement and Plan of Merger dated as of June 2, 2014, by and among the Company, Bogey, Inc., Koko'oha Investments, Inc., and Bill D. Mills, in his capacity as the Shareholders' Representative. Incorporated by reference to Exhibit 2.5 to the Company's Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2014, filed on August 11, 2014.

 2.4
 Amendment of Agreement and Plan of Merger dated as of September 9, 2014, by and among the Company, Bogey, Inc., Koko'oha Investments, Inc., and Bill D. Mills, in his capacity as the Shareholders' Representative. Incorporated by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K filed on September 10, 2014.

 2.5
 Second Amendment of Agreement and Plan of Merger dated as of December 31, 2014, by and among Par Petroleum Corporation, Bogey, Inc., Koko'oha Investments, Inc., and Bill D. Mills, in his capacity as the Shareholder's Representative. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on January 7, 2015.

 2.6
 Third Amendment to Agreement and Plan of Merger dated as of March 31, 2015, by and among the Company, Bogey, Inc., Koko'oha Investments, Inc., and Bill D. Mills, in his capacity as the Shareholders' Representative. Incorporated by reference to Exhibit 2.4 to the Company's Current Report on Form 8-K filed on April 2, 2015.

 2.7
 Unit Purchase Agreement, dated as of June 13, 2016, between Par Wyoming, LLC and Black Elk Refining, LLC. Incorporated by reference to Exhibit 2.1 to the Company's Current Report on Form 8-K filed on June 15, 2016.

 2.8
 First Amendment to Unit Purchase Agreement dated as of July 14, 2016, between Par Wyoming, LLC and Black Elk Refining, LLC. Incorporated by reference to Exhibit 2.2 to the Company's Current Report on Form 8-K filed on July 15, 2016.

 2.9
 Purchase and Sale Agreement dated as of November 26, 2018, among Par Petroleum, LLC, TrailStone NA Oil & Refining Holdings, LLC, and solely for certain purposes specified therein, the Company. Incorporated by reference to Exhibit 2.1 to the Company's Current Report on Form 8-K/A filed on November 30, 2018.#

 2.10
 Amendment No. 1 to Purchase and Sale Agreement dated as of January 11, 2019, among Par Petroleum, LLC, TrailStone NA Oil & Refining Holdings, LLC, and Par Pacific Holdings, Inc. Incorporated by reference to Exhibit 2.2 to the Company's Current Report on Form 8-K filed on January 14, 2019.

 2.11
 Equity and Asset Purchase Agreement dated as of October 20, 2022, by and among Exxon Mobil Corporation, ExxonMobil Oil Corporation and ExxonMobil Pipeline Company, LLC, as sellers, and Par Montana, LLC and Par Montana Holdings, LLC, as purchaser entities, and solely for the limited purposes set forth therein, Par Pacific Holdings, Inc. Incorporated by reference to Exhibit 2.1 to the Company's Current Report on Form 8-K filed on October 21, 2022.

 2.12
 First Amendment to Equity and Asset Purchase Agreement dated as of June 1, 2023, by and among Exxon Mobil Corporation, ExxonMobil Oil Corporation and ExxonMobil Pipeline Company, LLC, as sellers, and Par Montana, LLC, Par Montana Holdings, LLC, and Par Rocky Mountain Midstream, LLC, as purchaser entities, and solely for the limited purposes set forth therein, Par Pacific Holdings, Inc. Incorporated by reference to Exhibit 2.2 to the Company's Current Report on Form 8-K filed on June 1, 2023.

 3.1
 Restated Certificate of Incorporation of the Company dated October 20, 2015. Incorporated by reference to Exhibit 3.2 to the Company's Current Report on Form 8-K filed on October 20, 2015.

 3.2
 Second Amended and Restated Bylaws of the Company dated October 20, 2015. Incorporated by reference to Exhibit 3.3 to the Company's Current Report on Form 8-K filed on October 20, 2015.

 4.1
 Form of the Company's Common Stock Certificate. Incorporated by reference to Exhibit 4.1 to the Company's Annual Report on Form 10-K filed on March 31, 2014.

 4.2
 Registration Rights Agreement effective as of August 31, 2012, by and among the Company, Zell Credit Opportunities Master Fund, L.P., Waterstone Capital Management, L.P., Pandora Select Partners, LP, Iam Mini-Fund 14 Limited, Whitebox Multi-Strategy Partners, LP, Whitebox Credit Arbitrage Partners, LP, HFR RVA Combined Master Trust, Whitebox Concentrated Convertible Arbitrage Partners, LP, and Whitebox Asymmetric Partners, LP. Incorporated by reference to Exhibit 4.3 to the Company's Current Report on Form 8-K filed on September 7, 2012.

 4.3
 First Amendment to Registration Rights Agreement dated as of December 19, 2018, by and among the Company and the holders party thereto. Incorporated by reference to Exhibit 4.3 to the Company's registration statement on Form S-3 filed on December 21, 2018.

 4.4
 Stockholders Agreement dated April 10, 2015. Incorporated by reference to Exhibit 4.1 to the Company's Current Report on Form 8-K filed on April 13, 2015.

 4.5
 Description of Registrant's Securities. Incorporated by reference to Exhibit 4.13 to the Company's Annual Report on Form 10-K filed on February 27, 2023.

 10.1
 Fourth Amended and Restated Limited Liability Company Agreement of Laramie Energy, LLC, dated as of October 18, 2018, by and among Par Piceance Energy Equity LLC and the other members party thereto. Incorporated by reference to Exhibit 10.4 to the Company's Quarterly Report on Form 10-Q filed on November 7, 2018.

 10.2
 Par Pacific Holdings, Inc. Amended and Restated 2012 Long Term Incentive Plan. Incorporated by reference to Appendix A to the Company's Proxy Statement on Schedule 14A filed on April 21, 2016.****

 10.3
 Par Pacific Holdings, Inc. Second Amended and Restated 2012 Long Term Incentive Plan. Incorporated by reference to Exhibit 4.1 to the Company's registration statement on Form S-8 filed on May 18, 2018.****

 10.4
 Par Pacific Holdings, Inc. 2018 Employee Stock Purchase Plan. Incorporated by reference to Exhibit 4.2 to the Company's Registration Statement on Form S-8 filed on May 18, 2018.****

 10.5
 Form of Indemnification Agreement between the Company and its Directors and Executive Officers. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on October 19, 2012.****

 10.6
 Employment Offer Letter with William Monteleone dated September 25, 2013. Incorporated by reference to Exhibit 10.43 to the Company's Amendment No. 3 to Annual Report on Form 10-K/A filed on July 2, 2014.****

 10.7
 Form of Award of Restricted Stock (Discretionary Long Term Incentive Plan). Incorporated by reference to Exhibit 10.17 to the Company's Annual Report on Form 10-K filed on March 2, 2020.****

 10.8
 Form of Award of Performance Restricted Stock Units. *

 10.9
 Form of Nonstatutory Stock Option Agreement (Discretionary Long Term Incentive Plan). Incorporated by reference to Exhibit 10.14 to the Company's Annual Report on Form 10-K filed on February 27, 2023.

 10.10
 Par Petroleum (and subsidiaries) Incentive Compensation Plan. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on May 12, 2015.****

 10.11
 Second Amended and Restated Supply and Offtake Agreement dated as of June 1, 2021, between Par Hawaii Refining, LLC and J. Aron & Company, LLC. Incorporated by reference to Exhibit 10.2 to the Company's Quarterly Report on Form 10-Q filed on August 5, 2021.

 10.12
 Amended and Restated Guaranty dated June 1, 2021 in favor of J. Aron & Company LLC by Par Petroleum, LLC. Incorporated by reference to Exhibit 10.3 to the Company's Quarterly Report on Form 10-Q filed on August 5, 2021.

 10.13
 Environmental Indemnity Agreement dated as of June 1, 2015, by Hawaii Independent Energy, LLC in favor of J. Aron & Company. Incorporated by reference to Exhibit 10.7 to the Company's Current Report on Form 8-K filed June 2, 2015.

 10.14
 Employment Offer Letter with William C. Pate dated October 12, 2015. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed October 14, 2015.****

 10.15
 Employment Offer Letter with Richard Creamer dated March 29, 2022. Incorporated by reference to Exhibit 10.8 to the Company's Quarterly Report on Form 10-Q filed on August 9, 2022. ****

 10.16
 Employment Offer Letter with Eric Wright dated January 17, 2017. Incorporated by reference to Exhibit 10.5 to the Company's Quarterly Report on Form 10-Q filed on May 6, 2022. ****

 10.17
 Employment Offer Letter with Shawn Flores dated December 13, 2022. Incorporated by reference to Exhibit 10.23 to the Company's Annual Report on Form 10-K filed on February 27, 2023. ****

 10.18
 Par Pacific Holdings, Inc. Non-Qualified Deferred Compensation Plan. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on March 6, 2017.****

 10.19
 Par Pacific Holdings, Inc. Severance Plan for Senior Officers. Incorporated by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K filed on March 6, 2017. ****

 10.20
 Amendment #1 to the Par Pacific Holdings, Inc. Severance Plan for Senior Officers, dated as of May 1, 2017.*****

 10.21
 Amendment #2 to the Par Pacific Holdings, Inc. Severance Plan for Senior Officers, dated as of May 23, 2022. Incorporated by reference to Exhibit 10.1 to the Company's current report on Form 8-K filed on May 25, 2022. ****

 10.22
 Asset Purchase Agreement dated as of January 9, 2018 by and among CHS Inc., Par Hawaii, Inc., and Par Pacific Holdings, Inc. Incorporated by reference to Exhibit 10.2 to the Company's Quarterly Report on Form 10-Q filed on May 10, 2018. #

 10.23
 First Amendment to Asset Purchase Agreement dated as of March 23, 2018 by and among CHS Inc., Par Hawaii, Inc., and Par Pacific Holdings, Inc. Incorporated by reference to Exhibit 10.3 to the Company's Quarterly Report on Form 10-Q filed on May 10, 2018. #

 10.24
 Topping Unit Purchase Agreement by and among IES Downstream, LLC, Eagle Island, LLC, Par Hawaii Refining, LLC, and Par Pacific Holdings, Inc., dated as of August 29, 2018. Incorporated by reference to Exhibit 10.1 to the Company's Quarterly Report on Form 10-Q filed on November 7, 2018. #

 10.25
 Purchase Agreement and Escrow Instructions, dated as of February 11, 2021, by and among Par Hawaii, LLC, Par Pacific Hawaii Property Company, LLC, MDC Coast HI 1, LLC, and Fidelity National Title Insurance Company. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on February 16, 2021.

 10.26
 Amended and Restated Master Land and Building Lease Agreement, dated as of March 12, 2021, by and among Par Hawaii, LLC, Par Petroleum, LLC and MDC Coast HI 1, LLC. Incorporated by reference to Exhibit 10.2 to the Company's Quarterly Report on Form 10-Q filed on Form 8-K filed on May 7, 2021.

 10.27
 Second Amended and Restated Pledge and Security Agreement dated June 1, 2021 in favor of J. Aron & Company LLC by Par Hawaii Refining, LLC. Incorporated by reference to Exhibit 10.42 to the Company's Annual Report on Form 10-K filed on February 25, 2022.

 10.28
 Amendment to Second Amended and Restated Supply and Offtake Agreement dated as of March 24, 2022, between Par Hawaii Refining, LLC and J. Aron & Company, LLC. Incorporated by reference to Exhibit 10.2 to the Company's Quarterly Report on Form 10-Q filed on May 6, 2022.

 10.29
 Amendment to Second Amended and Restated Supply and Offtake Agreement, dated as of April 25, 2022, by and among Par Hawaii Refining LLC, Par Petroleum, LLC, as guarantor, and J. Aron & Company LLC. Incorporated by reference to Exhibit 10.1 to the Company's current report on Form 8-K filed on April 28, 2022.

 10.30
 Amendment to Second Amended and Restated Supply and Offtake Agreement, dated as of May 17, 2022, by and among Par Hawaii Refining LLC, Par Petroleum, LLC, as guarantor, and J. Aron & Company LLC. Incorporated by reference to Exhibit 10.1 to the Company's current report on Form 8-K filed on May 19, 2022.

 10.31
 Amendment to Second Amended and Restated Supply and Offtake Agreement, dated as of September 13, 2022, by and among Par Hawaii Refining LLC, Par Petroleum, LLC, as guarantor, and J. Aron & Company LLC. Incorporated by reference to Exhibit 10.1 to the Company's Quarterly Report on Form 10-Q filed on November 3, 2022.

 10.32
 Amendment to Second Amended and Restated Supply and Offtake Agreement, dated as of February 13, 2023, by and among Par Hawaii Refining LLC, Par Petroleum, LLC, as guarantor, and J. Aron & Company LLC. Incorporated by reference to Exhibit 10.54 to the Company's Annual Report on Form 10-K filed on February 27, 2023.

 10.33
 Term Loan Credit Agreement, dated as of February 28, 2023, by and among Par Pacific Holdings, Inc., as Holdings, Par Petroleum, LLC and Par Petroleum Finance Corp., as the Borrowers, Wells Fargo Bank, National Association, as Administrative Agent and the lenders that are parties thereto, as the Lenders. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on March 1, 2023.

 10.34
 Asset-Based Revolving Credit Agreement, dated as of April 26, 2023, by and among Par Pacific Holdings, Inc., as Holdings, Par Petroleum, LLC, Par Hawaii, LLC, Hermes Consolidated, LLC, Wyoming Pipeline Company LLC, Par Montana, LLC and Par Rocky Mountain Midstream, LLC, as Borrowers, Wells Fargo Bank, National Association, as Agent, Issuing Bank, and Swing Lender, the lenders party thereto, as the Lenders, and the other issuing banks party thereto, as Issuing Banks, and Wells Fargo Bank, National Association, Bank of America, N.A., Goldman Sachs Bank USA, MUFG Bank, LTD and Fifth Third Bank, National Association, as Joint Lead Arrangers and Joint Bookrunners. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on May 2, 2023.

 10.35
 First Amendment to Asset-Based Revolving Credit Agreement, dated as of May 30, 2023, by and among Par Pacific Holdings, Inc., as Holdings, Par Petroleum, LLC, Par Hawaii, LLC, Hermes Consolidated, LLC, Wyoming Pipeline Company LLC, Par Montana, LLC and Par Rocky Mountain Midstream, LLC, as Borrowers, Wells Fargo Bank, National Association, as Agent, Issuing Bank, and Swing Lender, the lenders party thereto, as the Lenders, and the other issuing banks party thereto, as Issuing Banks, and Wells Fargo Bank, National Association, Bank of America, N.A., Goldman Sachs Bank USA, MUFG Bank, LTD and Fifth Third Bank, National Association, as Joint Lead Arrangers and Joint Bookrunners. Incorporated by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K filed on June 1, 2023.

 10.36
 Amendment to Second Amended and Restated Supply and Offtake Agreement, dated as of June 21, 2023, by and among Par Hawaii Refining LLC, Par Petroleum, LLC, as guarantor, and J. Aron & Company LLC. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on June 26, 2023.

 10.37
 Uncommitted Credit Agreement, dated as of July 26, 2023, by and among Par Hawaii Refining, LLC, as borrower, each of the lenders and letter of credit issuers listed on the signature pages thereof, MUFG Bank, Ltd., as administrative agent for the lenders, sub-collateral agent, as joint lead arranger and sole bookrunner, Macquarie Bank Limited, as joint lead arranger, and U.S. Bank Trust Company, National Association, solely in its capacity as collateral agent. Incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on August 1, 2023.

 10.38
 Parent Guaranty, dated as of July 26, 2023, made by Par Petroleum, LLC, as guarantor. Incorporated by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K filed on August 1, 2023.

 10.39
 Amendment to Second Amended and Restated Supply and Offtake Agreement, dated as of July 26, 2023, by and among Par Hawaii Refining LLC, Par Petroleum, LLC, as guarantor, and J. Aron & Company LLC. Incorporated by reference to Exhibit 10.3 to the Company's Current Report on Form 8-K filed on August 1, 2023.

 10.40
 Third Amended and Restated Pledge and Security Agreement, dated as of July 26, 2023, by and among Par Hawaii Refining, LLC, J. Aron & Company LLC, MUFG Bank, Ltd., and U.S. Bank Trust Company, National Association, as collateral agent. Incorporated by reference to Exhibit 10.4 to the Company's Current Report on Form 8-K filed on August 1, 2023.

 10.41
 Collateral Agency and Intermediation Rights Agreement, dated as of July 26, 2023, by and among Par Hawaii Refining, LLC, MUFG Bank, Ltd., J. Aron & Company LLC, and U.S. Bank Trust Company, National Association, as collateral agent. Incorporated by reference to Exhibit 10.5 to the Company's Current Report on Form 8-K filed on August 1, 2023.

 10.42
 Second Amendment to Asset-Based Revolving Credit Agreement and Joinder Agreement dated October 4, 2023, among Par Petroleum, LLC, Par Hawaii, LLC, Hermes Consolidated, LLC, Wyoming Pipeline Company LLC, Par Montana, LLC, Par Rocky Mountain Midstream, LLC, U.S. Oil & Refining Co., the Company, the other loan parties party thereto, Wells Fargo Bank, National Association, and the incremental lenders and lenders party thereto. Incorporated by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K filed on October 10, 2023.

 10.43
 Limited Consent to Uncommitted Credit Agreement effective as of October 4, 2023, among Par Hawaii Refining, LLC, Par Petroleum, LLC, the lenders party thereto, MUFG Bank, Ltd., and U.S. Bank Trust Company, National Association, solely in its capacity as the collateral agent. Incorporated by reference to Exhibit 10.3 to the Company's Current Report on Form 8-K filed on October 10, 2023.

 10.44
 Employment Assignment Letter with Jeffrey R. Hollis dated December 15, 2022.*****

 14.1
 Par Pacific Holdings, Inc. Code of Business Conduct and Ethics for Employees, Executive Officers and Directors, effective December 3, 2015. Incorporated by reference to Exhibit 14.1 to the Company's Annual Report on Form 10-K filed March 3, 2016.

 21.1
 Subsidiaries of the Registrant.*

 23.1
 Consent of Deloitte & Touche LLP*

 31.1
 Certification of Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.*

 31.2
 Certification of Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.*

 32.1
 Certification of Chief Executive Officer Pursuant to 18 U.S.C. Section 1350.***

 32.2
 Certification of Chief Financial Officer Pursuant to 18 U.S.C. Section 1350.***

 97.1
 Par Pacific Holdings, Inc. Policy for the Recovery of Erroneously Awarded Compensation, effective October 24, 2023.*****

 101.INS

 101.SCH

 101.CAL

 101.LAB

 101.PRE

 101.DEF

 *
 Filed herewith.

 ***
 Furnished herewith.

 ****
 Management contract or compensatory plan or arrangement.

 #
 Portions of this exhibit have been redacted in accordance with Item 601(b)(10) of Regulation S-K.

 INDEX TO CONSOLIDATED FINANCIAL STATEMENTS

 Page No.

 Report of Independent Registered Public Accounting Firm
 Auditor Name: Deloitte & Touch LLP; Auditor Firm ID: 34; Auditor Location: Houston, Texas

 F- 2

 Consolidated Balance Sheets
 F- 5

 Consolidated Statements of Operations
 F- 6

 Consolidated Statements of Comprehensive Income (Loss)
 F- 7

 Consolidated Statements of Cash Flows
 F- 8

 Consolidated Statements of Changes in Stockholders' Equity
 F- 9

 F- 10

 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 To the shareholders and the Board of Directors of Par Pacific Holdings, Inc.
 Opinion on the Financial Statements
 We have audited the accompanying consolidated balance sheets of Par Pacific Holdings, Inc. and subsidiaries (the "Company") as of December 31, 2023 and 2022, the related consolidated statements of operations, comprehensive income (loss), cash flows and changes in stockholders' equity for each of the three years in the period ended December 31, 2023, and the related notes and the schedule listed in the Index at Item 15 (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2023 and 2022, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2023, in conformity with accounting principles generally accepted in the United States of America.
 We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 29, 2024 expressed an unqualified opinion on the Company's internal control over financial reporting.
 Basis for Opinion
 These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
 We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
 Critical Audit Matters
 The critical audit matters communicated below are matters arising from the current-period audit of the financial statements that were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
 Acquisitions – Billings Acquisition Valuation and Purchase Price Allocation – Refer to Note 5 to the financial statements
 Critical Audit Matter Description
 On June 1, 2023, the Company completed the acquisition of (i) the high-conversion, complex refinery located in Billings, Montana and certain associated distribution and logistics assets, (ii) a 65% limited partnership equity interest in Yellowstone Energy Limited Partnership, and (iii) a 40% equity interest in Yellowstone Pipeline Company (collectively, the "Billings Acquisition") for a total purchase price of $625.4 million, including working capital. The Company accounted for the Billings Acquisition as a business combination. Accordingly, the purchase price was allocated to the assets acquired and liabilities assumed based on their estimated fair values at the date of

 acquisition. Of the total purchase price, $259.1 million was allocated to property, plant and equipment. The valuation of property, plant, and equipment was determined based on the cost approach for refining process units, tanks, pipelines, and equipment and the market approach for land.
 We identified the valuation of property, plant and equipment related to the Billings Acquisition as a critical audit matter because of the significant estimates and assumptions made by management to determine the fair value of certain assets acquired and liabilities assumed. This required a high degree of auditor judgment and an increased extent of effort, including the involvement of our fair value specialists, when performing audit procedures to determine the fair value of acquired refining process units, tanks, pipelines, and equipment under the cost approach, including estimating cost to acquire or construct comparable assets adjusted for the remaining useful lives, and land under the market approach.
 How the Critical Audit Matter Was Addressed in the Audit
 Our audit procedures related to the fair value of assets acquired and liabilities assumed for the Billings Acquisition included the following, among others:
 • We tested the effectiveness of controls over the purchase price allocation, including management's controls over the assumptions used in the cost approach for refining process units, tanks, pipelines and equipment, including estimating the cost to acquire or construct comparable assets adjusted for remaining useful lives, the assumptions used in the market approach for land and their review of the work of third-party specialists.
 • With the assistance of our fair value specialists
 We evaluated the appropriateness of selected valuation methodologies;
 We evaluated the cost to acquire or construct comparable assets for the cost approach for refining process units, tanks, pipelines, and equipment, including comparing such estimates to source information; and
 We tested the underlying source information used for the market approach for land.
 • We considered any events or transactions occurring after the Billings Acquisition date that may indicate a different valuation for the assets acquired and liabilities assumed.
 Summary of Significant Accounting Policies – Management Projections Used in Goodwill and Deferred Taxes Valuation Allowance Analyses – Refer to Notes 2, 11 and 22 to the financial statements
 Critical Audit Matter Description
 Management of the Company prepares and uses projected operational results ("Management's Projections") for various accounting analysis and considerations, including the annual goodwill impairment test of certain reporting units and the determination of any valuation allowance against deferred tax assets. The development of Management's Projections involves management making significant judgments and assumptions in estimating future cash flows, including assumptions related to future gross margins, operating expenses and levels of sustaining capital expenditures.
 Given that the development of Management's Projections require management to make significant estimates related to assumptions, performing audit procedures to evaluate the reasonableness of these assumptions required a high degree of auditor judgment and an increased extent of effort.
 How the Critical Audit Matter Was Addressed in the Audit
 Our audit procedures related to Management's Projections included the following, among others:
 • We evaluated the effectiveness of controls over the determination of Management's Projections, including management's controls over the determination of the underlying projections of future gross margins, operating expenses, and levels of sustaining capital expenditures.

 • We evaluated management's ability to accurately forecast by comparing actual results to management's historical forecasts.
 • We evaluated the reasonableness of Management's Projections by
 Comparing the projections to historical financial results;
 Comparing the projections to internal communications between management and the Board of Directors; and
 Comparing trends in the projections to analyst and Industry reports for the Company and certain of its peer companies
 • We evaluated the impact of changes in Management's Projections from the projection date to December 31, 2023.

 /s/ Deloitte & Touche LLP
 Houston, Texas
 February 29, 2024

 We have served as the Company's auditor since 2013.

 CONSOLIDATED BALANCE SHEETS
 (in thousands, except share data)

 ASSETS

 Current assets

 Cash and cash equivalents
 $
 279,107
 $
 490,925

 Restricted cash
 4,001

 Total cash, cash equivalents, and restricted cash
 279,446
 494,926

 Trade accounts receivable, net of allowances of $ 0.2 million and $ 0.3 million at December 31, 2023 and December 31, 2022, respectively

 367,249
 252,885

 1,160,395
 1,041,983

 182,405
 92,043

 Total current assets
 1,989,495
 1,881,837

 1,577,801
 1,224,567

 ( 478,413)
 ( 388,733)

 1,099,388
 835,834

 Long-term assets

 Operating lease right-of-use ("ROU") assets
 346,454
 350,761

 Refining and logistics equity investments
 87,486
 —

 Investment in Laramie Energy, LLC
 14,279
 —

 Intangible assets, net
 13,577

 129,275
 129,325

 186,655
 69,313

 $
 $

 LIABILITIES AND STOCKHOLDERS' EQUITY

 Current liabilities

 Current maturities of long-term debt
 $
 4,255
 $
 10,956

 893,065

 Accounts payable
 391,325
 151,395

 Accrued taxes
 40,064
 32,099

 72,833
 66,081

 421,762
 640,494

 Total current liabilities
 1,524,601
 1,794,090

 Long-term liabilities

 Long-term debt, net of current maturities
 646,603
 494,576

 Finance lease liabilities
 12,438
 6,311

 282,517
 292,701

 Other liabilities
 62,367
 48,432

 2,528,526
 2,636,110

 Commitments and Contingencies (Note 18)

 Stockholders' equity

 Preferred stock, $ 0.01 par value: 3,000,000 shares authorized, none issued

 —
 —

 Common stock, $ 0.01 par value; 500,000,000 shares authorized at December 31, 2023 and December 31, 2022, 59,755,844 shares and 60,470,837 shares issued at December 31, 2023 and December 31, 2022, respectively

 Additional paid-in capital

 Accumulated earnings (deficit)
 ( 200,687)

 Accumulated other comprehensive income
 8,174
 8,129

 Total stockholders' equity

 Total liabilities and stockholders' equity
 $
 $

 CONSOLIDATED STATEMENTS OF OPERATIONS
 (in thousands, except per share amounts)

 2023
 2022
 2021

 $
 $
 $

 —
 —
 1,838

 ( 11,844)
 —
 —

 3,663

 9,003
 9,591

 ( 59)
 ( 169)
 ( 64,697)

 7,551,949
 6,883,882
 4,717,708

 ( 7,619)

 ( 72,450)
 ( 68,288)
 ( 66,493)

 ( 19,182)
 ( 5,329)
 ( 8,144)

 —
 —
 2,032

 ( 53)
 ( 52)

 —
 —

 Total other expense, net
 ( 66,700)
 ( 73,004)
 ( 72,657)

 613,306
 364,899
 ( 80,276)

 Income tax benefit (expense)
 115,336
 ( 710)
 ( 1,021)

 $
 $
 $

 Income (loss) per share

 Basic
 $
 12.14
 $
 6.12
 $
 ( 1.40)

 Diluted
 $
 11.94
 $
 6.08
 $
 ( 1.40)

 Weighted-average number of shares outstanding

 Basic
 60,035
 59,544
 58,268

 Diluted
 61,014
 59,883
 58,268

 CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

 2023
 2022
 2021

 $
 $
 $

 Other comprehensive income:

 Other post-retirement benefits income, net of tax
 5,627
 6,244

 Total other comprehensive income, net of tax
 5,627
 6,244

 Comprehensive income (loss)
 $
 728,687
 $
 369,816
 $
 ( 75,053)

 CONSOLIDATED STATEMENTS OF CASH FLOWS

 2023
 2022
 2021

 Cash flows from operating activities:

 $
 $
 $

 Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:

 —
 —
 1,838

 19,182
 5,329
 8,144

 Non-cash interest expense
 4,645
 4,218
 5,663

 Non-cash lower of cost and net realizable value adjustment
 —
 ( 463)
 ( 10,132)

 Deferred taxes
 ( 126,267)
 ( 260)

 ( 59)
 ( 169)
 ( 64,697)

 11,633
 9,353
 8,165

 Unrealized (gain) loss on derivative contracts
 ( 49,689)
 9,336
 ( 1,393)

 ( 24,985)
 —
 —

 ( 11,844)
 —
 —

 Dividends received from refining and logistics investments
 4,328
 —
 —

 Net changes in operating assets and liabilities:

 Trade accounts receivable
 ( 112,421)
 ( 57,391)
 ( 83,955)

 Prepaid and other assets
 ( 82,027)
 ( 35,356)
 ( 6,321)

 180,235
 ( 254,437)
 ( 350,652)

 Deferred turnaround expenditures
 ( 5,851)
 ( 29,608)
 ( 9,451)

 ( 91,624)
 74,680
 252,920

 Accounts payable, other accrued liabilities, and operating lease ROU assets and liabilities
 15,428
 262,882
 209,565

 Net cash provided by (used in) operating activities
 579,156
 452,606
 ( 27,622)

 Cash flows from investing activities:

 Acquisitions of businesses, net of cash acquired
 ( 595,420)
 ( 35,546)
 —

 ( 82,277)
 ( 53,025)
 ( 29,533)

 Proceeds from sale of assets
 1,322
 1,263
 104,161

 Return of capital from Laramie Energy, LLC
 10,706
 —
 —

 Return of capital from refining and logistics investments
 6,630
 —
 —

 Net cash provided by (used in) investing activities
 ( 659,039)
 ( 87,308)
 74,628

 Cash flows from financing activities:

 Proceeds from sale of common stock, net of offering costs
 —
 —
 87,193

 Proceeds from borrowings
 1,462,850
 384,874
 186,773

 Repayments of borrowings
 ( 1,317,709)
 ( 446,863)
 ( 329,315)

 Net borrowings (repayments) on deferred payment arrangements and receivable advances
 ( 95,985)
 80,681
 61,098

 Payment of deferred loan costs
 ( 14,371)
 —
 —

 ( 67,821)
 ( 7,834)
 ( 2,145)

 17,129
 6,444

 Payments for termination of inventory financing agreements
 ( 112,594)
 —
 —

 Payments for debt extinguishment and commitment costs and termination of inventory financing agreements
 ( 8,742)
 ( 3,483)
 ( 5,618)

 Other financing activities, net
 1,646
 ( 412)

 Net cash provided by (used in) financing activities
 ( 135,597)
 13,407
 ( 1,094)

 Net increase (decrease) in cash, cash equivalents, and restricted cash
 ( 215,480)
 378,705
 45,912

 Cash, cash equivalents, and restricted cash at beginning of period
 494,926
 116,221
 70,309

 Cash, cash equivalents, and restricted cash at end of period
 $
 279,446
 $
 494,926
 $
 116,221

 Supplemental cash flow information:

 Net cash received (paid) for:

 Interest
 $
 ( 77,417)
 $
 ( 63,323)
 $
 ( 65,221)

 Taxes
 ( 6,099)
 ( 51)
 ( 795)

 Non-cash investing and financing activities:

 Accrued capital expenditures
 $
 13,241
 $
 5,418
 $
 8,177

 ROU assets obtained in exchange for new finance lease liabilities
 7,896
 1,936

 ROU assets obtained in exchange for new operating lease liabilities
 72,219
 64,567
 97,011

 ROU assets terminated in exchange for release from operating lease liabilities
 1,439
 32,902
 6,847

 CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY

 Accumulated

 Additional
 Other

 Common Stock
 Paid-In
 Accumulated
 Comprehensive
 Total

 Shares
 Amount
 Capital
 Deficit
 Income
 Equity

 Balance, January 1, 2021
 54,003
 $
 $
 726,504
 $
 ( 477,028)
 $
 ( 3,742)
 $
 246,274

 Common stock offering, net of issuance costs
 5,750
 87,135
 —
 —
 87,193

 Issuance of common stock for employee stock purchase plan
 1,420
 —
 —
 1,421

 7,948
 —
 —
 7,952

 ( 123)
 ( 1)
 ( 1,352)
 ( 792)
 —
 ( 2,145)

 —
 —
 —

 Other comprehensive income
 —
 —
 —
 —
 6,244
 6,244

 Net loss
 —
 —
 —
 —

 Balance, December 31, 2021
 60,162
 821,713
 ( 559,117)
 2,502
 265,700

 Issuance of common stock for employee stock purchase plan
 —
 1,244
 —
 —
 1,244

 9,163
 —
 —
 9,166

 ( 524)
 ( 5)
 ( 2,069)
 ( 5,759)
 —
 ( 7,833)

 6,440
 —
 —
 6,444

 Other comprehensive income
 —
 —
 —
 —
 5,627
 5,627

 —
 —
 —
 —

 Balance, December 31, 2022
 60,471
 ( 200,687)
 8,129

 Issuance of common stock for employee stock purchase plan
 —
 1,937
 —
 —
 1,937

 11,336
 —
 —
 11,342

 ( 1,946)
 ( 19)
 ( 6,090)
 ( 62,099)
 —
 ( 68,208)

 17,123
 —
 —
 17,129

 Other comprehensive income
 —
 —
 —
 —

 —
 —
 —
 —

 Balance, December 31, 2023
 59,756
 $
 $
 $
 $
 8,174
 $

 Note 1— Overview
 Par Pacific Holdings, Inc. and its wholly owned subsidiaries ("Par" or the "Company") provide both renewable and conventional fuels to the western United States. Currently, we operate in three primary business segments:
 1) Refining - We own and operate four refineries. Our refineries in Kapolei, Hawaii, Newcastle, Wyoming, Tacoma, Washington, and Billings, Montana, convert crude oil into gasoline, distillate, asphalt and other products to serve the state of Hawaii and areas ranging from Washington state to the Dakotas and Wyoming.
 2) Retail - We operate fuel retail outlets in Hawaii, Washington, and Idaho. We operate convenience stores and fuel retail sites under our "Hele" and "nomnom" brands, "76" branded fuel retail sites and other sites operated by third parties that sell gasoline, diesel, and retail merchandise such as soft drinks, prepared foods, and other sundries. We also operate unattended cardlock stations.
 3) Logistics - We operate an extensive multi-modal logistics network spanning the Pacific, the Northwest, and the Rocky Mountain regions. This network includes a single point mooring ("SPM") in Hawaii, a unit train-capable rail loading terminal in Washington, and other terminals, pipelines, trucking operations, marine vessels, storage facilities, loading and truck racks, and rail facilities for the movement of petroleum, refined products, and ethanol in and among the Hawaiian islands, between the U.S. West Coast and Hawaii, and in areas ranging from the state of Washington to the Dakotas and Wyoming.
 As of December 31, 2023, we owned a 46 % equity investment in Laramie Energy, LLC ("Laramie Energy"). Laramie Energy is focused on developing and producing natural gas in Garfield, Mesa, and Rio Blanco counties, Colorado. As of December 31, 2023, through the Billings Acquisition (as defined in Note 5—Acquisitions), we own a 65 % and a 40 % equity investment in Yellowstone Energy Limited Partnership, ("YELP") and Yellowstone Pipeline Company ("YPLC"), respectively.
 Our Corporate and Other reportable segment primarily includes general and administrative costs.

 Note 2— Summary of Significant Accounting Policies
 Principles of Consolidation and Basis of Presentation
 The consolidated financial statements include the accounts of Par Pacific Holdings, Inc. and its subsidiaries. All intercompany balances and transactions have been eliminated in consolidation.
 Certain amounts previously reported in our consolidated financial statements for prior periods have been reclassified to conform to the current presentation, including Par West redevelopment and other costs, previously included in Operating expenses (excluding depreciation) in the Consolidated Statements of Operations and now reflected as a separate financial statement line item, and the presentation of deferred tax assets and liabilities associated with right-of-use liabilities ("ROU liabilities") and right-of-use assets ("ROU assets"), respectively, previously presented on a net basis are now presented on a gross basis in Note 22—Income Taxes.
 Use of Estimates
 The preparation of our consolidated financial statements in conformity with U.S. generally accepted accounting principles ("GAAP") requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses and the related disclosures. Actual amounts could differ from these estimates.
 Cash and Cash Equivalents
 Cash and cash equivalents consist of all highly liquid investments with original maturities of three months or less. The carrying value of cash equivalents approximates fair value because of the short-term nature of these investments.

 Restricted Cash
 Restricted cash consists of cash not readily available for general purpose cash needs. Restricted cash relates to cash held at commercial banks to support letter of credit facilities and certain ongoing bankruptcy recovery trust claims.
 Allowance for Credit Losses
 We are exposed to credit losses primarily through our sales of refined products. Credit limits and/or prepayment requirements are set based on such factors as the customer's financial results, credit rating, payment history, and industry and are reviewed annually for customers with material credit limits. Credit allowances are reviewed at least quarterly based on changes in the customer's creditworthiness due to economic conditions, liquidity, and business strategy as publicly reported and through discussions between the customer and the Company. We establish provisions for losses on trade receivables based on the estimated credit loss we expect to incur over the life of the receivable. We did not have a material change in our allowances on trade receivables during the years ended December 31, 2023, 2022, or 2021.
 Commodity inventories, excluding commodity inventories at the Washington refinery, are stated at the lower of cost and net realizable value ("NRV") using the first-in, first-out ("FIFO") inventory accounting method. Commodity inventories at the Washington refinery are stated at the lower of cost and NRV using the last-in, first-out ("LIFO") inventory accounting method. We value merchandise along with spare parts, materials, and supplies at average cost.
 All of the crude oil utilized at the Hawaii refinery is financed by J. Aron & Company LLC ("J. Aron") under the Supply and Offtake Agreement as described in Note 12—Inventory Financing Agreements. The crude oil remains in the legal title of J. Aron and is stored in our storage tanks governed by a storage agreement. Legal title to the crude oil passes to us at the tank outlet. After processing, J. Aron takes title to the refined products stored in our storage tanks until they are sold to our retail locations or to third parties. We record the inventory owned by J. Aron on our behalf as inventory with a corresponding obligation on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties and we are obligated to repurchase the inventory. Additionally, certain of the crude oil utilized at the Hawaii refinery is also financed by the LC Facility as described in Note 12—Inventory Financing Agreements. We also finance certain inventories at our other refineries through our ABL Credit Facility; please read Note 14—Debt for further information.
 We were party to an intermediation arrangement (the "Washington Refinery Intermediation Agreement") with Merrill Lynch Commodities, Inc. ("MLC") as described in Note 12—Inventory Financing Agreements. Under this arrangement, U.S. Oil & Refining Co. and certain affiliated entities (collectively, "U.S. Oil") purchased crude oil supplied from third-party suppliers and MLC provided credit support for certain crude oil purchases. MLC's credit support consisted of either providing a payment guaranty, causing the issuance of a letter of credit from a third-party issuing bank, or purchasing crude oil directly from third parties on our behalf. U.S. Oil held title to all crude oil and refined products inventories at all times and pledged such inventories, together with all receivables arising from the sales of these inventories, exclusively to MLC. On October 4, 2023, we terminated the Washington Refinery Intermediation Agreement; please read Note 12—Inventory Financing Agreements for further information.
 We enter into refined product and crude oil exchange agreements with other oil companies. Exchange receivables or payables are stated at cost and are presented within Trade accounts receivable and Accounts payable on our consolidated balance sheets.
 Environmental Credits and Obligations
 Inventories also include Renewable Identification Numbers ("RINs") and other environmental credits. Our environmental credit assets, which include RINs and other environmental credits are purchased through the open market, State of Washington auctions, or obtained by purchasing biofuels. These biofuels are later blended into our refined fuels and other credits generated as part of our refining process which are presented as Inventories on our consolidated balance sheets and stated at the lower of cost and NRV as of the end of the reporting period.
 Our renewable volume obligation and other environmental credit obligations to comply with the U.S. Environmental Protection Agency ("EPA") regulations (as discussed in Note 18—Commitments and Contingencies) are presented in Other accrued liabilities on our consolidated balance sheets and were historically measured at fair value as of the end of the reporting period.

 During the quarter ended December 31, 2023, we had a change in estimate in our valuation of our gross environmental credit obligations due to the settlement of all outstanding prior period environmental credit obligations (obligations associated with pre-2023 activities) and our prospective plan to use our RIN assets to settle future environmental obligations. Beginning in the fourth quarter of 2023, the portion of the estimated gross environmental credit obligations satisfied by internally generated or purchased RINs or other environmental credits is recorded at the carrying value of such internally generated or purchased RINs or other environmental credits. The remainder of the estimated gross environmental credit obligation is recorded at the market price of the RINs or other environmental credits that are needed to satisfy the remaining obligation as of the end of the reporting period. Under the previous valuation technique, our liability would have been $ 295.9 million as of December 31, 2023, and net income would have been lower with $ 9.0 million for the year ended December 31, 2023. Please read Note 16—Fair Value Measurements for further information. The net cost of environmental credits is recognized within Cost of revenues (excluding depreciation) on our consolidated statements of operations.
 Investment in Laramie Energy, LLC
 Effective February 21, 2023, we accounted for our Investment in Laramie Energy, LLC using the equity method as we have the ability to exert significant influence, but do not control its operating and financial policies. Our proportionate share of the net income (loss) of this entity was included in Equity earnings from Laramie Energy, LLC in the consolidated statements of operations. Prior to February 21, 2023, we did not apply the equity method of accounting for our investment in Laramie Energy because the book value of such investment had been reduced to zero. The investment is reviewed for impairment when events or changes in circumstances indicate that there may have been an other-than-temporary decline in the value of the investment. Please read Note 4—Investment in Laramie Energy for further information.
 Property, Plant, and Equipment
 We capitalize the cost of additions, major improvements, and modifications to property, plant, and equipment. The cost of repairs and normal maintenance of property, plant, and equipment is expensed as incurred. Major improvements and modifications of property, plant, and equipment are those expenditures that either extend the useful life, increase the capacity, or improve the operating efficiency of the asset or the safety of our operations. We compute depreciation of property, plant, and equipment using the straight-line method, based on the estimated useful life of each asset as follows:

 Assets
 Lives in Years

 2 to 47

 3 to 30

 3 to 40

 Corporate
 3 to 7

 Software
 3 to 5

 From time to time, we enter into lease arrangements where we are the lessor in order to utilize a portion of our fixed assets not currently used in our primary operations. All of these lessor leases are classified as operating leases, whereby we do not derecognize the underlying asset, and the income from our customers is recognized as revenue on a straight-line basis over the lease term. Please read Note 17—Leases for further disclosures and information on leases.
 Impairment of Long-Lived Assets
 We review property, plant, and equipment, operating leases, deferred turnaround costs, and other long-lived assets for impairment whenever events or changes in business circumstances indicate the carrying value of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets' carrying value. If this occurs, an impairment loss is recognized for the difference between the fair value and carrying value. Factors that indicate potential impairment include a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset, and a significant change in the asset's physical condition or use.
 Simultaneously with our review of our property, plant, and equipment, operating leases, deferred turnaround costs, and other long-lived assets for impairment, we evaluate whether an abandonment has occurred. Abandonment occurs either when a business terminates its operations or an asset is no longer profitable to operate. When the act of abandonment occurs, we write off the asset balance and any associated accumulated depreciation and record an impairment loss as needed.

 Lease Liabilities and Right-of-Use Assets
 We determine whether a contract is or contains a lease when we have the right to control the use of the identified asset in exchange for consideration. Lease liabilities and ROU assets are recognized at the commencement date based on the present value of lease payments over the lease term. We use our incremental borrowing rate in the calculation of present value unless the implicit rate can be readily determined, however, the lease liability associated with leases calculated through the use of implicit rates is not significant. Certain leases include provisions for variable payments based upon percentage of sales and/or other operating metrics; escalation provisions to adjust rental payments to reflect changes in price indices and fair market rents; and provisions for the renewal, termination, and/or purchase of the leased asset. We only consider fixed payments and those options that are reasonably certain to be exercised in the determination of the lease term and the initial measurement of lease liabilities and ROU assets. Expense for finance leases is recognized as amortization expense on a straight-line basis and interest expense on an effective rate basis over the lease term. Expense for operating lease payments is recognized as lease expense on a straight-line basis over the lease term. We do not separate lease and nonlease components of a contract. Leases with an initial term of 12 months or less are not recorded on the balance sheet. Finance lease ROU assets are presented within Property, plant, and equipment and operating lease ROU assets within Operating lease right-of-use assets on our consolidated balance sheets. Please read Note 17—Leases for further disclosures and information on leases.
 Asset Retirement Obligations
 We record asset retirement obligations ("AROs") at fair value in the period in which we have a legal obligation, whether by government action or contractual arrangement, to incur these costs and can make a reasonable estimate of the fair value of the liability. Our AROs arise from our refining, logistics, and retail operations. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate. When the liability is initially recorded, we capitalize the cost by increasing the book value of the related long-lived tangible asset. The liability is accreted to its estimated settlement value with accretion expense recognized in Depreciation and amortization ("D&A") on our consolidated statements of operations and the related capitalized cost is depreciated over the asset's useful life. The difference between the settlement amount and the recorded liability is recorded as a gain or loss on asset disposals in our consolidated statements of operations. We estimate settlement dates by considering our past practice, industry practice, contractual terms, management's intent, and estimated economic lives.
 We cannot currently estimate the fair value for certain AROs primarily because we cannot estimate settlement dates (or ranges of dates) associated with these assets. These AROs include hazardous materials disposal (such as petroleum manufacturing by-products, chemical catalysts, and sealed insulation material containing asbestos) and removal or dismantlement requirements associated with the closure of our refining facilities, terminal facilities, or pipelines, including the demolition or removal of certain major processing units, buildings, tanks, pipelines, or other equipment.
 Deferred Turnaround Costs
 Refinery turnaround costs, which are incurred in connection with planned major maintenance activities at our refineries, are deferred and amortized on a straight-line basis over the period of time estimated until the next planned turnaround (generally three to five years). During 2023, 2022, and 2021, we recognized deferred turnaround costs of approximately $ 5.9 million, $ 29.6 million, and $ 9.5 million, respectively. Deferred turnaround costs are presented within Other long-term assets on our consolidated balance sheets.
 Goodwill and Other Intangible Assets
 Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. Goodwill is not amortized, but is tested for impairment annually on October 1. We assess the recoverability of the carrying value of goodwill during the fourth quarter of each year or whenever events or changes in circumstances indicate that the carrying amount of the goodwill of a reporting unit may not be fully recoverable. We first assess qualitative factors to determine whether it is more likely than not that the fair value of the reporting unit is less than its carrying value. If the qualitative assessment indicates that it is more likely than not that the carrying value of a reporting unit exceeds its estimated fair value, a quantitative test is required. Under the quantitative test, we compare the carrying value of the net assets of the reporting unit to the estimated fair value of the reporting unit. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment loss is recorded.
 Our intangible assets include relationships with customers, trade names, and trademarks. These intangible assets are amortized over their estimated useful lives on a straight-line basis. We evaluate the carrying value of our intangible assets when impairment indicators are present. When we believe impairment indicators may exist, projections of the undiscounted future

 cash flows associated with the use of and eventual disposition of the intangible assets are prepared. If the projections indicate that their carrying values are not recoverable, we reduce the carrying values to their estimated fair values.
 Environmental Matters
 We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed, and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Usually, the timing of these accruals coincides with the completion of a feasibility study or our commitment to a formal plan of action. Estimated liabilities are not discounted to present value and are presented within Other liabilities on our consolidated balance sheets. Environmental expenses are recorded in Operating expense (excluding depreciation) on our consolidated statements of operations.
 Derivatives and Other Financial instruments
 We are exposed to commodity price risk related to crude oil, refined products, and environmental credits. We manage this exposure through the use of various derivative commodity instruments. These instruments include exchange traded futures and over-the-counter ("OTC") swaps, forwards, and options.
 For our forward contracts that are derivatives, we have elected the normal purchase normal sale exclusion, as it is our policy to fulfill or accept the physical delivery of the product and we will not net settle. Therefore, we did not recognize the unrealized gains or losses related to these contracts in our consolidated financial statements.
 All derivative instruments not designated as normal purchases or sales are recorded in the balance sheet as either assets or liabilities measured at their fair values. Changes in the fair value of these derivative instruments are recognized currently in earnings. We have not designated any derivative instruments as cash flow or fair value hedges and, therefore, do not apply hedge accounting treatment.
 In addition, we may have other financial instruments, such as warrants or embedded debt features, that may be classified as liabilities when either (a) the holders possess rights to net cash settlement, (b) physical or net equity settlement is not in our control, or (c) the instruments contain other provisions that cause us to conclude that they are not indexed to our equity. Our embedded derivatives include our obligations to repurchase crude oil and refined products from J. Aron at the termination of the Supply and Offtake Agreement. These liabilities were initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings.
 Please read Note 15—Derivatives and Note 16—Fair Value Measurements for information regarding our derivatives and other financial instruments.
 Income Taxes
 We use the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and net operating loss ("NOL") and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted income tax rates expected to apply to taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in income tax rates is recognized in the results of operations in the period that includes the enactment date. The realizability of deferred tax assets is evaluated quarterly based on a "more likely than not" standard and, to the extent this threshold is not met, a valuation allowance is recorded. We do not have any unrecognized tax benefits as of December 31, 2023.
 As a general rule, our open years for Internal Revenue Service ("IRS") examination purposes are 2020, 2021, and 2022. However, since we have NOL carryforwards, the IRS has the ability to make adjustments to items that originate in a year otherwise barred by the statute of limitations in order to re-determine tax for an open year to which those items are carried. Therefore, in a year in which a NOL deduction is claimed, the IRS may examine the year in which the NOL was generated and adjust it accordingly for purposes of assessing additional tax in the year the NOL deduction was claimed. Any penalties or interest as a result of an examination will be recorded in the period assessed.

 Stock-Based Compensation
 We recognize the cost of share-based payments on a straight-line basis over the period the employee provides service, generally the vesting period, and include such costs in General and administrative expense (excluding depreciation) and Operating expense (excluding depreciation) in the consolidated statements of operations. We account for forfeitures as they occur. The grant date fair value of restricted stock awards is equal to the market price of our common stock on the date of grant. The fair value of stock options is estimated using the Black-Scholes option-pricing model as of the date of grant. The fair value of the discount offered on the employee stock purchase plan is equal to 15 % of the market price of our common stock on the purchase date.
 Revenue Recognition
 Refining and Retail
 Our refining and retail segment revenues are primarily associated with the sale of refined products. We recognize revenues upon physical delivery of refined products to a customer, which is the point in time at which control of the refined products is transferred to the customer. The pricing of our refined products is variable and primarily driven by commodity prices. The refining segment's contracts with its customers state the terms of the sale, including the description, quantity, delivery terms, and price of each product sold. Payments from refining and bulk retail customers are generally due in full within 2 to 30 days of product delivery or invoice date. Payments from our other retail customers occur at the point of sale and are typically collected in cash or occur by credit or debit card. As such, we have no significant financing element to our revenues and have immaterial product returns and refunds.
 We account for certain transactions on a net basis under Financial Accounting Standards Board ("FASB") ASC Topic 845, "Nonmonetary Transactions." These transactions include nonmonetary crude oil and refined product exchange transactions, certain crude oil buy/sell arrangements, and sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another.
 We made an accounting policy election to apply the sales tax practical expedient, whereby all taxes assessed by a governmental authority that are both imposed on and concurrent with a revenue-producing transaction and collected from our customers will be recognized on a net basis within Cost of revenues (excluding depreciation).
 We recognize transportation and storage fees as services are provided to a customer. Substantially all of our logistics revenues represent intercompany transactions that are eliminated in consolidation.
 Cost Classifications
 Cost of revenues (excluding depreciation) includes the hydrocarbon-related costs of inventory sold, transportation costs of delivering product to customers, crude oil consumed in the refining process, costs to satisfy our environmental credit obligations, and certain hydrocarbon fees and taxes. Cost of revenues (excluding depreciation) also includes the unrealized gains and losses on derivatives and inventory valuation adjustments. Certain direct operating expenses related to our logistics segment are also included in Cost of revenues (excluding depreciation).
 Operating expense (excluding depreciation) includes direct costs of labor, maintenance and services, energy and utility costs, property taxes, and environmental compliance costs, as well as chemicals and catalysts and other direct operating expenses.
 The following table summarizes depreciation and finance lease amortization expense excluded from each line item in our consolidated statements of operations (in thousands):

 2023
 2022
 2021

 Cost of revenues
 $
 24,980
 $
 20,437
 $
 21,903

 Operating expense
 66,886
 51,901
 52,338

 General and administrative expense
 2,142
 2,661
 2,972

 Benefit Plans
 We recognize an asset for the overfunded status or a liability for the underfunded status of our defined benefit pension plans. The funded status is recorded within Other liabilities on our consolidated balance sheets. Certain changes in the plans' funded status are recognized in Other comprehensive income (loss) in the period the change occurs.
 Fair Value Measurements
 Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value measurements are categorized with the highest priority given to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority given to unobservable inputs. The three levels of the fair value hierarchy are as follows:
 Level 1 – Assets or liabilities for which the item is valued based on quoted prices (unadjusted) for identical assets or liabilities in active markets.
 Level 2 – Assets or liabilities valued based on observable market data for similar instruments.
 Level 3 – Assets or liabilities for which significant valuation assumptions are not readily observable in the market; instruments valued based on the best available data, some of which is internally-developed and considers risk premiums that a market participant would require.
 The level in the fair value hierarchy within which the fair value measurement is categorized is based on the lowest level input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. Our policy is to recognize transfers in and/or out of fair value hierarchy levels as of the end of the reporting period for which the event or change in circumstances caused the transfer. We have consistently applied these valuation techniques for the periods presented. The fair value of the J. Aron repurchase obligation derivatives are measured using estimates of the prices and differentials assuming settlement at the end of the reporting period.
 Income (Loss) Per Share
 Basic income (loss) per share ("EPS") is computed by dividing net income (loss) attributable to common stockholders by the sum of the weighted-average number of common shares outstanding and the weighted-average number of shares issuable under the warrants. The common stock warrants were included in the calculation of basic EPS because they were issuable for minimal consideration. Basic and diluted EPS are computed taking into account the effect of participating securities. Participating securities include restricted stock that has been issued but has not yet vested. Please read Note 21—Income (Loss) Per Share for further information.
 Foreign Currency Transactions
 We may, on occasion, enter into transactions denominated in currencies other than the U.S. dollar, which is our functional currency. Gains and losses resulting from changes in currency exchange rates between the functional currency and the currency in which a transaction is denominated are included in Other income (expense), net, in the accompanying consolidated statement of operations in the period in which the currency exchange rates change. For the years ended December 31, 2023, 2022, or 2021, gains and losses resulting from changes in currency translations were immaterial.
 Accounting Principles Not Yet Adopted
 In November 2023, the FASB issued Accounting Standards Update ("ASU") No. 2023-07, Improvements to Reportable Segment Disclosures (Topic 280) ("ASU 2023-07"). The amendments in ASU 2023-07 improves reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. Public entities are required to disclose significant segment expenses by reportable segment if they are regularly provided to the Chief Operating Decision Maker ("CODM") and included in each reported measure of segment profit or loss. The purpose of the amendments is to enable investors to better understand an entity's overall performance and assess potential future cash flows. The guidance in ASU 2023-07 is effective for fiscal years beginning after December 15, 2024. This ASU therefore does not impact our 2023 Form 10-K. Par will assess the impact of this ASU on our 2024 Form 10-K annual segment disclosures as part of our fiscal year 2024 procedures.
 On December 14, 2023, the FASB issued ASU 2023-09, Improvements to Income Tax Disclosure (Topic 740). This ASU requires public business entities to disclose additional information in specified categories with respect to the reconciliation of the effective tax rate to the statutory rate for federal, state, and foreign income taxes. It also requires greater detail about

 individual reconciling items in the rate reconciliation to the extent the impact of those items exceeds a specified threshold. Additionally, the ASU requires information pertaining to taxes paid (net of refunds received) to be disaggregated for federal, state, and foreign taxes and further disaggregated for specific jurisdictions to the extent the related amounts exceed a quantitative threshold. The guidance in ASU 2023-09 is effective for fiscal years beginning after December 15, 2025. This ASU therefore does not impact our 2023 Form 10-K. Par will assess the impact of this ASU on our 2025 Form 10-K annual segment disclosures as part of our fiscal year 2025 procedures.
 Accounting Principles Adopted
 On January 1, 2022, we adopted ASU No. 2021-08, Business Combinations (Topic 805): Accounting for Contract Assets and Contract Liabilities from Contracts with Customers ("ASU 2021-08"). This ASU changes accounting for recording contract assets and liabilities acquired in a business combination to improve comparability and consistency. During the Billings Acquisition in June 2023, no contract assets or liabilities were acquired, thus our adoption of ASU 2021-08 will not impact on our financial condition, results of operations, and cash flows.
 On January 1, 2022, we adopted ASU No. 2022-04, Liabilities - Supplier Finance Programs (Subtopic 405-50) Disclosure of Supplier Finance Program Obligations ("ASU 2022-04"). This ASU defines supplier finance programs and establishes new disclosure requirements for such programs. For programs meeting that definition, this ASU requires annual disclosures of key terms, obligations, and certain information related to these programs. Interim disclosure of the amount of outstanding obligations is also required. Par's inventory financing agreements do not meet all the necessary criteria within scope of this ASU, therefore our adoption of ASU 2022-04 will not have a material impact on our financial condition, results of operations, and cash flows.

 Note 3—Refining and Logistics Equity Investments
 Yellowstone Energy Limited Partnership
 On June 1, 2023, we completed the Billings Acquisition (as defined in Note 5—Acquisitions) and acquired a 65 % limited partnership ownership interest in YELP. YELP owns a cogeneration facility in Billings, Montana, that converts petroleum coke, supplied from our Montana refinery and other nearby third-party refineries, into power production for the local utility grid. We account for our investment in YELP using the equity method as we have the ability to exert significant influence over, but do not control, its operating and financial policies. Our proportionate share of YELP's net income and the depreciation of our basis difference are included in Equity earnings from refining and logistics investments on our consolidated statements of operations due to the significance of YELP's cogeneration facilities to our Montana operations. Our proportionate share of YELP's net income (loss) is recorded on a one-month lag.
 The change in our equity investment in YELP is as follows (in thousands):

 For the period from June 1 through December 31,

 2023

 Beginning balance
 $
 —

 Acquisition of investment
 58,019

 Equity earnings from YELP

 8,059

 Depreciation of basis difference
 ( 696)

 Dividends received
 ( 5,558)

 Ending balance
 $
 59,824

 Yellowstone Pipeline Company
 On June 1, 2023, we completed the Billings Acquisition (as defined in Note 5—Acquisitions) and acquired a 40 % ownership interest in YPLC. YPLC owns a refined products pipeline that begins at our Montana refinery and transports refined product throughout Montana and the Pacific Northwest. We account for our ownership interest in YPLC using the equity method as we have the ability to exert significant influence over, but do not control, its operating and financial policies. Our proportionate share of YPLC's net income and the accretion of our basis difference is included in Equity earnings from refining and logistics investments on our consolidated statements of operations due to the significance of YPLC's distribution services to our Montana operations.

 The change in our equity investment in YPLC is as follows (in thousands):

 For the period from June 1 through December 31,

 2023

 Beginning balance
 $
 —

 Acquisition of investment
 28,581

 Equity earnings from YPLC

 4,392

 Accretion of basis difference

 Dividends received
 ( 5,400)

 Ending balance
 $
 27,662

 Note 4— Investment in Laramie Energy
 As of December 31, 2023, we owned a 46 % ownership interest in Laramie Energy, an entity focused on developing and producing natural gas in Garfield, Mesa, and Rio Blanco counties, Colorado. The balance of our investment in Laramie Energy was $ 14.3 million as of December 31, 2023. As of December 31, 2022, the book value of our investment was zero.
 Prior to February 21, 2023, Laramie Energy had a term loan agreement which provided a term loan secured by a lien on its natural gas and crude oil properties and related assets. Under the terms of the term loan, Laramie Energy was generally prohibited from making future cash distributions to its owners, including us, except for certain permitted tax distributions.
 On February 21, 2023, Laramie Energy entered into a term loan agreement which provides a $ 205 million first lien term loan facility with $ 160.0 million funded at closing and an optional $ 45 million delayed draw commitment, subject to certain terms and conditions. Laramie Energy used the proceeds from the term loan to repay the then-outstanding balance of $ 76.3 million on its existing term loan, including accrued interest and prepayment penalties, and fully redeem preferred equity of $ 73.5 million. After deducting transaction costs, net proceeds were $ 4.8 million. Under the terms of the new term loan, Laramie is permitted to make future cash distributions to its owners, including us, subject to certain restrictions. Laramie Energy's term loan matures on February 21, 2027. As of December 31, 2023 and 2022, the term loan had an outstanding balance of $ 160.0 million and $ 77.4 million, respectively.
 On March 1, 2023, pursuant to its new term loan agreement, Laramie Energy made a one-time cash distribution to its owners, including us, based on ownership percentage. Our share of this distribution was $ 10.7 million, which was reflected as Return of capital from Laramie Energy, LLC on our consolidated statements of cash flows. We recorded the cash received as Equity earnings from Laramie Energy, LLC on our consolidated statements of operations because the carrying value of our investment in Laramie Energy was zero at the time of such distribution.
 Effective February 21, 2023, and concurrent with Laramie's entry into the new term loan agreement noted above, we resumed the application of equity method accounting with respect to our investment in Laramie Energy. At December 31, 2023, our equity in the underlying net assets of Laramie Energy exceeded the carrying value of our investment by approximately $ 71.7 million.
 The change in our equity investment in Laramie Energy is as follows (in thousands):

 2023

 Beginning balance
 $
 —

 Equity earnings (losses) from Laramie Energy
 19,471

 Accretion of basis difference
 5,514

 Distribution received
 ( 10,706)

 Ending balance

 $
 14,279

 Note 5— Acquisitions
 Billings Acquisition
 On October 20, 2022, we and our subsidiaries Par Montana, LLC ("Par Montana") and Par Montana Holdings, LLC ("Par Montana Holdings"), entered into an equity and asset purchase agreement (as amended to include Par Rocky Mountain Midstream, LLC, the "Purchase Agreement") with Exxon Mobil Corporation, ExxonMobil Oil Corporation, and ExxonMobil Pipeline Company LLC (collectively, the "Sellers") to purchase (i) the high-conversion, complex refinery located in Billings, Montana and certain associated distribution and logistics assets, (ii) the Sellers' 65 % limited partnership equity interest in YELP, and (iii) the Sellers' 40 % equity interest in YPLC for a base purchase price of $ 310.0 million plus the value of hydrocarbon inventory and adjusted working capital at closing (collectively, the "Billings Acquisition"). The Billings Acquisition enhances our fully integrated downstream network in the upper Rockies and Pacific Northwest. The Billings Acquisition increases scale and geographic diversification on the U.S. mainland and allows for efficient access to alternative markets.
 On June 1, 2023, we completed the Billings Acquisition for a total purchase price of approximately $ 625.4 million, including acquired working capital, consisting of a cash deposit of $ 30.0 million paid on October 20, 2022 upon execution of the Purchase Agreement and $ 595.4 million paid at closing on June 1, 2023. The Company funded the Billings Acquisition with cash on hand and borrowings from the ABL Credit Facility (as defined in Note 14—Debt).
 We accounted for the Billings Acquisition as a business combination whereby the purchase price was allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of acquisition. A summary of the preliminary fair value of the assets acquired and liabilities assumed is as follows (in thousands):

 Trade accounts receivable
 $
 2,387

 299,176

 259,088

 Operating lease right-of-use assets
 3,562

 Investment in refining and logistics subsidiaries
 86,600

 4,094

 Total assets (1)
 654,907

 Current operating lease liabilities
 2,081

 Other current liabilities
 7,056

 Environmental liabilities
 18,869

 Long-term operating lease liabilities
 1,481

 29,487

 Total
 $
 625,420

 _______________________________________________________
 (1)We allocated $ 538.7 million and $ 116.2 million of total assets to our refining and logistics segments, respectively.
 We have recorded a preliminary estimate of the fair value of the assets acquired and liabilities assumed and expect to finalize the purchase price allocation during the first part of 2024. The primary areas of the purchase price allocation that are not finalized as of December 31, 2023 relate to property, plant, and equipment and the environmental liabilities. During the year ended December 31, 2023, immaterial purchase price allocation adjustments were recorded related to working capital. Any final valuation adjustments could change the fair values assigned to the assets acquired and liabilities assumed, resulting in a change to our consolidated financial statements, which could be material.
 We incurred $ 10.4 million and $ 3.4 million of acquisition costs related to the Billings Acquisition for the year ended December 31, 2023 and 2022, respectively. These costs are included in Acquisition and integration costs on our consolidated statements of operations.
 We assumed certain environmental liabilities associated with the Billings Acquisition, including costs related to hazardous waste corrective measures, ground and surface water sampling and monitoring. We expect to incur these costs over a 20 to 30 year period.

 The results of operations of the Montana refinery, newly acquired logistics assets in the Rockies region, and YELP and YPLC equity investments were included in our results beginning on June 1, 2023. For the year ended December 31, 2023, our results of operations included revenues of $ 1.5 billion, and net income of $ 57.9 million, related to these assets. The following unaudited pro forma financial information presents our consolidated revenues and net income as if the Billings Acquisition had been completed on January 1, 2022 (in thousands):

 2023
 2022

 $
 9,172,821
 $
 10,033,522

 847,740
 419,441

 These pro forma results were based on estimates and assumptions that we believe are reasonable. The unaudited pro forma financial information is not necessarily indicative of the results of operations that would have been achieved had the Billings Acquisition been effective as of the dates presented, nor is it indicative of future operating results of the combined company. Pro forma adjustments include (i) incremental depreciation resulting from the estimated fair value of property, plant, and equipment acquired, (ii) transaction costs which were shifted from the year ended December 31, 2023 to the year ended December 31, 2022, (iii) elimination of historical transactions between Par and the Montana assets, and (iv) incremental income tax expense at Par's effective income tax rate, adjusted for non-recurring items, on the pre-tax pro forma results.
 Northwest Retail Expansion
 On December 2, 2022, we purchased three retail stores in Washington, for total consideration of $ 5.5 million (the "Northwest Retail Expansion"). We accounted for the Northwest Retail Expansion as a business combination whereby the purchase price was allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of acquisition. Of the total purchase price of $ 5.5 million, $ 2.0 million was allocated to property, plant, and equipment, $ 0.8 million was allocated to lease valuation, and $ 0.5 million was allocated to inventory. We recognized $ 2.1 million in goodwill attributable to opportunities expected to arise from expanding our operations. During the year ended December 31, 2023, $ 50 thousand of the 2022 purchase payment was refunded to us; the refund was accounted for as a reduction of goodwill. We incurred $ 0.3 million of acquisition costs related to the Northwest Retail Expansion for the year ended December 31, 2022. These costs are included in Acquisition and integration costs on our consolidated statement of operations.

 Note 6— Revenue Recognition
 As of December 31, 2023 and 2022, receivables from contracts with customers were $ 311.1 million and $ 242.5 million, respectively. Our refining segment recognizes deferred revenues when cash payments are received in advance of delivery of products to the customer. Deferred revenue was $ 15.2 million and $ 11.5 million as of December 31, 2023 and 2022, respectively. We have elected to apply a practical expedient not to disclose the value of unsatisfied performance obligations for (i) contracts with an original expected duration of less than one year and (ii) contracts where the variable consideration has been allocated entirely to our unsatisfied performance obligation.
 The following table provides information about disaggregated revenue by major product line and includes a reconciliation of the disaggregated revenues to total segment revenues (in thousands):

 Year Ended December 31, 2023

 Product or service:

 Gasoline
 $
 2,689,350
 $
 —
 $
 438,058

 Distillates (1)
 3,412,819
 —
 49,651

 Other refined products (2)
 1,718,961
 —
 —

 Merchandise
 —
 —
 101,529

 Transportation and terminalling services
 —
 260,779
 —

 Other revenue
 148,350
 —
 3,242

 Total segment revenues (3)
 $
 7,969,480
 $
 260,779
 $
 592,480

 Year Ended December 31, 2022

 Product or service:

 Gasoline
 $
 1,999,065
 $
 —
 $
 428,959

 Distillates (1)
 3,139,807
 —
 46,392

 Other refined products (2)
 1,890,813
 —
 —

 Merchandise
 —
 —
 91,289

 Transportation and terminalling services
 —
 198,821
 —

 Other revenue
 16,375
 —
 3,566

 Total segment revenues (3)
 $
 7,046,060
 $
 198,821
 $
 570,206

 Year Ended December 31, 2021

 Product or service:

 Gasoline
 $
 1,472,335
 $
 —
 $
 333,396

 Distillates (1)
 1,927,851
 —
 27,057

 Other refined products (2)
 1,065,555
 —
 —

 Merchandise
 —
 —
 92,004

 Transportation and terminalling services
 —
 184,734
 —

 Other revenue
 5,370
 —
 3,959

 Total segment revenues (3)
 $
 4,471,111
 $
 184,734
 $
 456,416

 _______________________________________________________
 (1)Distillates primarily include diesel and jet fuel.
 (2)Other refined products include fuel oil, gas oil, and asphalt.
 (3) Refer to Note 23—Segment Information for the reconciliation of segment revenues to total consolidated revenues.

 Note 7— Inventories
 Inventories at December 31, 2023 and 2022 consisted of the following (in thousands):

 Titled Inventory
 Supply and Offtake Agreement (1)
 Total

 Crude oil and feedstocks
 $
 175,307
 $
 168,549
 $
 343,856

 Refined products and blendstock
 358,236
 133,684
 491,920

 Warehouse stock and other (2)
 324,619
 —
 324,619

 Total
 $
 858,162
 $
 302,233
 $
 1,160,395

 Crude oil and feedstocks
 $
 112,082
 $
 265,536
 $
 377,618

 Refined products and blendstock
 188,040
 168,624
 356,664

 Warehouse stock and other (2)
 307,701
 —
 307,701

 Total
 $
 607,823
 $
 434,160
 $
 1,041,983

 (1)Please read Note 12—Inventory Financing Agreements for further information.
 (2)Includes $ 237.6 million and $ 258.2 million of RINs and environmental credits, reported at the lower of cost or NRV, as of December 31, 2023 and 2022, respectively. Our renewable volume obligation and other gross environmental credit obligations of $ 286.9 million and $ 549.8 million, are included in Other accrued liabilities on our consolidated balance sheets as of December 31, 2023 and 2022, respectively.
 Inventories valued on the LIFO method were approximately 26 % and 22 % of total inventories at December 31, 2023 and 2022, respectively. As of December 31, 2023 and December 31, 2022, there was no reserve for the lower of cost or net

 realizable value of inventory. As of December 31, 2023 and December 31, 2022, the current replacement cost exceeded the LIFO inventory carrying value by approximately $ 36.1 million and $ 46.4 million, respectively.

 Note 8— Prepaid and Other Current Assets
 Prepaid and other current assets at December 31, 2023 and 2022 consisted of the following (in thousands):

 2023
 2022

 Advances to suppliers for crude purchases
 $
 65,531
 $
 —

 Collateral posted with broker for derivative instruments (1)
 21,763
 40,788

 Billings Acquisition deposit (2)
 —
 30,000

 Prepaid insurance
 20,235
 15,639

 Derivative assets
 43,356
 —

 Prepaid environmental credits
 20,756
 —

 Other
 10,764
 5,616

 Total
 $
 182,405
 $
 92,043

 (1)Our cash margin that is required as collateral deposits on our commodity derivatives cannot be offset against the fair value of open contracts except in the event of default. Please read Note 15—Derivatives for further information.
 (2)Please read Note 5—Acquisitions for further discussion.

 Note 9— Property, Plant, and Equipment and Impairment of Long-Lived Assets
 Major classes of property, plant, and equipment, including assets acquired under finance leases, consisted of the following (in thousands):

 2023
 2022

 Land
 $
 194,623
 $
 153,804

 Buildings and equipment (1)
 1,361,828
 1,050,898

 Other (1)
 21,350
 19,865

 Total property, plant, and equipment
 1,577,801
 1,224,567

 ( 478,413)
 ( 388,733)

 $
 1,099,388
 $
 835,834

 ______________________________________________________
 (1)Please read Note 17—Leases for further disclosures and information on finance leases.
 Depreciation and finance lease amortization expense was approximately $ 94.0 million, $ 75.0 million, and $ 77.2 million for the years ended December 31, 2023, 2022, and 2021, respectively.
 The Par West refinery was idled in the first quarter of 2020 due to the reduction in demand resulting from the COVID-19 global pandemic's effect on the economy. Pursuant to GAAP accounting guidelines, this refinery was deemed abandoned in the fourth quarter of 2020 due to the following factors: the idling of the assets for more than an insignificant amount of time, the significant cost to restart the refinery, and a lack of a current plan or timeline to restart the refinery. For the year ended December 31, 2021, we recorded additional impairment charges of $ 0.2 million in Impairment expense on our consolidated statement of operations related to this idling. Please read Note 16—Fair Value Measurements for additional information.
 For the year ended December 31, 2021, we recorded $ 1.7 million of Impairment expense on our consolidated statement of operations related to the impairment of a separate capital project. For the years ended December 31, 2022 and 2023, no such impairment was recorded.

 Note 10— Asset Retirement Obligations
 Our asset retirement obligations ("AROs") are primarily related to the removal of underground storage tanks and the removal of brand signage at owned and leased retail sites which are legally required, whether by government action or contractual arrangement. The table below summarizes the changes in our recorded AROs (in thousands):

 2023
 2022
 2021

 Beginning balance
 $
 15,375
 $
 14,414
 $
 10,636

 Accretion expense

 Revision in estimate
 —
 3,602

 Liabilities settled during period
 —
 ( 89)
 ( 697)

 Ending balance
 $
 16,340
 $
 15,375
 $
 14,414

 Note 11— Goodwill and Intangible Assets
 During the years ended December 31, 2023, 2022, and 2021, the change in the net carrying amount of goodwill was as follows (in thousands):

 Balance at January 1, 2021
 $
 127,997

 Divestitures
 ( 735)

 Balance at December 31, 2021
 127,262

 Acquisition (1)
 2,120

 Divestitures
 ( 57)

 Balance at December 31, 2022
 129,325

 Divestitures (2)
 ( 50)

 Balance at December 31, 2023
 $
 129,275

 (1)Please read Note 5—Acquisitions for further discussion.
 (2)In December 2022, we purchased three retail stores in Washington. $ 50 thousand of the 2022 payment was refunded to us in 2023; the refund was accounted for as a reduction of goodwill. Please read Note 5—Acquisitions for further discussion.

 The gross carrying value of goodwill was $ 202.9 million as of December 31, 2021, $ 205.0 million as of December 31, 2022, and $ 205.0 million as of December 31, 2023. As of December 31, 2021, 2022, and 2023, we had cumulative charges related to divestitures of $ 75.6 million, $ 75.7 million, and $ 75.8 million, respectively.

 Intangible assets consisted of the following (in thousands):

 2023
 2022

 Intangible assets:

 Trade names and trademarks
 $
 6,267
 $
 6,267

 Customer relationships
 32,064
 32,064

 Other

 Total intangible assets
 38,592
 38,592

 Accumulated amortization:

 Trade name and trademarks
 ( 5,470)
 ( 5,383)

 Customer relationships
 ( 22,204)
 ( 19,632)

 Other
 —
 —

 Total accumulated amortization
 ( 27,674)
 ( 25,015)

 Net:

 Trade name and trademarks

 Customer relationships
 9,860
 12,432

 Other

 Total intangible assets, net
 $
 $
 13,577

 Amortization expense was approximately $ 2.7 million for each of the years ended December 31, 2023, 2022, and 2021. Our intangible assets related to customer relationships and trade names have an average useful life of 13.5 years. Expected amortization expense for each of the next five years and thereafter is as follows (in thousands):

 Year Ended
 Amount

 2024
 $
 1,400

 2025

 2026

 2027

 2028

 Thereafter
 5,602

 $

 Note 12— Inventory Financing Agreements
 The following table summarizes our outstanding obligations under our inventory financing agreements (in thousands):

 2023
 2022

 Supply and Offtake Agreement

 $
 $
 732,511

 Washington Refinery Intermediation Agreement
 —
 160,554

 LC Facility due 2024

 —
 —

 $
 $
 893,065

 Supply and Offtake Agreement
 We have a supply and offtake agreement with J. Aron to support our Hawaii refining operations (the "Supply and Offtake Agreement"). On June 1, 2021, we entered into the second amended and restated supply and offtake agreement, which amended and restated the first amended and restated supply and offtake agreement in its entirety. During the term of the Supply and Offtake Agreement, J. Aron and we will identify mutually acceptable contracts for the purchase of crude oil from third

 parties. Per the agreement, J. Aron will provide up to 150 Mbpd of crude oil to our Hawaii refinery. Additionally, we will sell, and J. Aron will buy, at market prices, refined products produced at our Hawaii refinery. We will then repurchase the refined products from J. Aron prior to selling the refined products to our retail operations or to third parties. Under the agreement, J. Aron may enter into agreements with third parties whereby J. Aron remits payments to these third parties for refinery procurement contracts for which we will become immediately obligated to reimburse J. Aron. The agreement also provides for the lease of crude oil and certain refined product storage facilities to J. Aron.
 The Supply and Offtake Agreement expires May 31, 2024 (as extended, the "Expiration Date"). Under the Supply and Offtake Agreement, we would have been subject to an early termination fee if we terminated the Supply and Offtake Agreement prior to May 31, 2023. Following the expiration or termination of the agreement, we are obligated to purchase the crude oil and refined product inventories then owned by J. Aron and located at the leased storage facilities at then-current market prices. Under the Supply and Offtake Agreement, Par Hawaii Refining, LLC ("PHR") is required to maintain minimum liquidity of not less than $ 15 million for any three consecutive business days, with at least $ 15 million of such liquidity consisting of cash and cash equivalents.
 Though title to the crude oil and certain refined product inventories resides with J. Aron, the Supply and Offtake Agreement is accounted for similar to a product financing arrangement; therefore, the crude oil and refined products inventories will continue to be included in our consolidated balance sheets until processed and sold to a third party. Each reporting period, we record a liability in an amount equal to the amount we expect to pay to repurchase the inventory held by J. Aron based on current market prices.
 Prior to July 1, 2021, the Supply and Offtake Agreement also included a deferred payment arrangement whereby we could defer payments owed under the agreements up to the lesser of $ 165 million or 85 % of the eligible accounts receivable and inventory. The deferred amounts under the deferred payment arrangement bore interest at a rate equal to three-month LIBOR plus 3.50 % per annum. We also paid a deferred payment availability fee equal to 0.75 % of the unused capacity under the deferred payment arrangement.
 Effective July 1, 2021, a discretionary draw facility (the "Discretionary Draw Facility") became available to PHR up to but excluding the Expiration Date. Under the Discretionary Draw Facility, J. Aron agreed to make advances to PHR from time to time at the request of PHR, subject to the satisfaction of certain conditions precedent, in an aggregate principal amount at any one time outstanding not to exceed the lesser of $ 165 million or the sum of the borrowing base, which is calculated as (x) 85 % of the eligible accounts receivables, plus (y) the lesser of $ 82.5 million and 85 % of eligible hydrocarbon inventory, minus (z) such reserves as established by J. Aron in respect of eligible receivables and eligible hydrocarbon inventory. Prior to June 1, 2022, the advances under the Discretionary Draw Facility bore interest at a rate equal to three-month LIBOR plus 4.00 % per annum. Beginning on June 1, 2022, the advances bear interest at a rate equal to LIBOR (or LIBOR equivalent) plus an applicable spread between 3.50 % and 4.00 % to be determined annually based on certain financial ratios. We also pay a discretionary draw availability fee equal to 0.75 % of the unused capacity under the Discretionary Draw Facility.
 On April 25, 2022, we entered into an amendment (the "S&O Amendment") to the Supply and Offtake Agreement which, among other things, amended the maximum commitment amount under the Discretionary Draw Facility from $ 165 million to $ 215 million. The S&O Amendment further increased the limit in the borrowing base for eligible hydrocarbon inventory from $ 82.5 million to $ 107.5 million. The S&O Amendment further requires a $ 5.0 million reserve against the borrowing base at any time more than $ 165 million is outstanding in discretionary draw advances made to PHR; the reserve may be reduced by the posting of cash collateral by PHR in accordance with the terms of the S&O Amendment. On February 13, 2023, we entered into an amendment to the Supply and Offtake Agreement to, among other things, facilitate entry into the Term Loan Credit Agreement. On June 21, 2023, we entered into an amendment (the "June 2023 S&O Amendment") to the Supply and Offtake Agreement to establish the Secured Overnight Financing Rate ("SOFR"), as defined in the Supply and Offtake Agreement, as the benchmark rate in replacement of the London Interbank Offered Rate ("LIBOR") and revise certain other terms and conditions, effective July 1, 2023. On July 26, 2023, we entered into an amendment (the "July 2023 S&O Amendment") to the Supply and Offtake Agreement which, among other things, allowed PHR to enter into a crude oil procurement contract supported by a letter of credit under the LC Facility (as defined below) and have its purchases funded by J. Aron, subject to certain conditions. Please read below for further information on the LC Facility.
 Under the Supply and Offtake Agreement, we pay or receive certain fees from J. Aron based on changes in market prices over time. In 2021 and 2022, we entered into multiple contracts to fix certain market fees for the period from January 2022 through May 2022 for $ 8.7 million. For the year ended December 31, 2023, we did not enter into any contracts to fix market fees related to our Supply and Offtake Agreement. The amount due to or from J. Aron is recorded as an adjustment to our Obligations under inventory financing agreements as allowed under the Supply and Offtake Agreement. We did not recognize any fixed market fees due for the year ended December 31, 2023. We recognized fixed market fees of $ 8.8 million

 and $ 13.5 million for the years ended December 31, 2022, and 2021, respectively, which were included in Cost of revenues (excluding depreciation) on our consolidated statements of operations.
 LC Facility due 2024
 On July 26, 2023, PHR, as borrower, the lenders and letter of credit issuing banks party thereto (collectively, the "LC Facility Lenders"), MUFG Bank, Ltd., as administrative agent (the "LC Facility Agent"), sub-collateral agent, joint lead arranger and sole bookrunner, Macquarie Bank Limited, as joint lead arranger, and U.S. Bank Trust Company, National Association, as collateral agent (the "Collateral Agent"), entered into an Uncommitted Credit Agreement (the "LC Facility Agreement") whereby the LC Facility Lenders agree, on an uncommitted and absolutely discretionary basis, to consider making revolving credit loans and issuing and participating in letters of credit in the maximum available amount of $ 120.0 million in the aggregate (the "LC Facility") with the right to request an increase up to $ 350.0 million in the aggregate, subject to certain conditions. Letters of credit issued under the LC Facility are intended to finance and provide credit support for certain of PHR's purchases of crude oil. In addition, revolving credit loans may be used to pay suppliers. The LC Facility will mature on July 25, 2024, unless the obligations are accelerated and the maximum credit limits of the LC Facility Lenders are terminated prior to such date.
 The revolving credit loans under the LC Facility bear interest at a 1) SOFR rate plus the applicable margin of 2.5 %, 2) cost of funds rate plus applicable margin of 2.5 % or 3) alternate base rate plus 1.5 %, as more particularly described in the LC Facility Agreement.
 PHR has agreed to pay certain fees and commissions with respect to letters of credit under the LC Facility, including, but not limited to, a letter of credit commission, in an amount equal to the greater of $ 750 (in dollars) and (1) 2.00 % per annum of the face amount of any trade letter of credit, or (2) 2.25 % per annum of the face amount of any performance letter of credit, each payable monthly in arrears. In addition, PHR shall pay a fronting fee equal to 0.25 % of the face amount of each letter of credit issued by a letter of credit issuing bank, payable monthly in arrears.
 The LC Facility Agreement requires PHR to comply with various covenants, including compliance with the minimum liquidity covenant. PHR agrees that it shall not permit the liquidity of PHR for any three consecutive business days to be less than $ 15 million at any time, with at least $ 15 million of such liquidity consisting of cash and cash equivalents. PHR has granted a lien and security interest in certain of its assets to the Collateral Agent. PHR is also required to provide cash collateral to the LC Facility Agent as a condition to issuance of certain letters of credit.
 On October 4, 2023, PHR, and Par Petroleum, LLC, obtained the written consent from the lenders party to the LC Facility to permit the Second Amendment to ABL Credit Facility (as defined in Note 14—Debt) and to amend certain defined terms or provisions in the ABL Credit Facility, pursuant to that certain Limited Consent to Uncommitted Credit Agreement dated as of October 3, 2023, among PHR, Par Petroleum, LLC, each of the lenders party thereto, LC Facility Agent, and U.S. Bank Trust Company, National Association, solely in its capacity as the collateral agent (the "Limited Consent"). Refer to Note 14—Debt for further information on the Second Amendment to ABL Credit Facility.
 Washington Refinery Intermediation Agreement
 Prior to December 31, 2023, we were party to the Washington Refinery Intermediation Agreement with MLC, which provided a structured financing arrangement based on U.S. Oil's crude oil and refined products inventories and associated accounts receivable. Under this arrangement, U.S. Oil purchased crude oil supplied from third-party suppliers and MLC provided credit support for such crude oil purchases. MLC's credit support consisted of either providing a payment guaranty, causing the issuance of a letter of credit from a third-party issuing bank, or purchasing crude oil directly from third parties on our behalf. U.S. Oil held title to all crude oil and refined products inventories at all times and pledged such inventories, together with all receivables arising from the sales of the same, exclusively to MLC.
 On October 4, 2023, U.S. Oil entered into a wind-down and termination agreement (the "Wind-Down Agreement") with MLC, which provided for the wind down of the respective obligations of MLC and U.S. Oil. Under the Wind-Down Agreement, in exchange for cash collateral provided by U.S. Oil to MLC, the payment of certain fees by U.S. Oil to MLC, and the satisfaction of other conditions precedent specified in the Wind-Down Agreement, MLC released all of its liens and security interests in all collateral, and MLC and U.S. Oil terminated the First Lien ISDA Agreement, Collateral Agreement, and all other guarantee and collateral documents, other than certain surviving obligations and certain other obligations which specifically continue under the terms of the Wind-Down Agreement. In connection with the Wind-Down Agreement, we recognized a termination fee of $ 1.5 million, which were recorded in Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2023. The cash paid to settle the obligation is included in Payments for termination of inventory financing agreements in our consolidated statements of cash flows for the year ended December

 31, 2023. As of December 31, 2023, there were no outstanding obligations under the Washington Refinery Intermediation Agreement.
 The following table summarizes our outstanding borrowings, letters of credit, and contractual undertaking obligations under the intermediation agreements (in thousands):

 2023
 2022

 Discretionary Draw Facility

 Outstanding borrowings (1)

 $
 165,459
 $
 204,843

 Borrowing capacity

 175,891
 204,843

 MLC receivable advances

 Outstanding borrowings (1)

 —
 56,601

 Borrowing capacity

 —
 56,601

 LC Facility due 2024

 Outstanding borrowings
 —
 —

 Borrowing capacity
 120,000
 —

 MLC issued letters of credit

 —
 115,001

 LC Facility issued letters of credit
 13,000
 —

 ______________________________________________________
 (1)Borrowings outstanding under the Discretionary Draw Facility and MLC receivable advances are included in Obligations under inventory financing agreements on our consolidated balance sheets. Changes in the borrowings outstanding under these arrangements are included within Cash flows from financing activities on the consolidated statements of cash flows.
 The following table summarizes the inventory intermediation fees, which are included in Cost of revenues (excluding depreciation) on our consolidated statements of operations, and Interest expense and financing costs, net related to the intermediation agreements (in thousands):

 2023
 2022
 2021

 Net fees and expenses:

 Supply and Offtake Agreement

 Inventory intermediation fees (1)
 $
 56,164
 $
 100,610
 $
 21,612

 7,149
 6,150
 3,015

 Washington Refinery Intermediation Agreement

 Inventory intermediation fees
 2,250
 3,000
 3,236

 9,280
 10,111
 4,900

 LC Facility due 2024

 1,667
 —
 —

 ___________________________________________________
 (1)Inventory intermediation fees under the Supply and Offtake Agreement include market structure fees of $ 13.5 million, $ 63.3 million, and $ 4.0 million for the years ended December 31, 2023, 2022, and 2021, respectively.
 The Supply and Offtake Agreement and, prior to its termination, the Washington Refinery Intermediation Agreement also provide us with the ability to economically hedge price risk on our inventories and crude oil purchases. Please read Note 15—Derivatives for further information.

 Note 13— Other Accrued Liabilities

 Other accrued liabilities at December 31, 2023 and 2022 consisted of the following (in thousands):

 2023
 2022

 Accrued payroll and other employee benefits
 $
 40,533
 $
 27,815

 Gross environmental credit obligations (1)
 286,904
 549,791

 Derivative liabilities

 27,725
 10,989

 Deferred revenue

 15,220
 11,457

 Other
 51,380
 40,442

 Total
 $
 421,762
 $
 640,494

 ______________________________________________________
 (1)Please read Note 16—Fair Value Measurements for further information. A portion of these obligations are expected to be settled with our RINs assets and other environmental credits, which are presented as Inventories on our consolidated balance sheet and are stated at the lower of cost or net realizable value. The carrying costs of these assets were $ 237.6 million and $ 258.2 million as of December 31, 2023 and 2022, respectively.

 Note 14— Debt
 The following table summarizes our outstanding debt (in thousands):

 2023
 2022

 ABL Credit Facility due 2028

 $
 115,000
 $
 —

 Term Loan Credit Agreement due 2030

 545,875
 —

 7.75 % Senior Secured Notes due 2025

 —
 281,000

 Term Loan B Facility due 2026

 —
 203,125

 12.875 % Senior Secured Notes due 2026

 —
 31,314

 Other long-term debt
 4,746
 —

 Principal amount of long-term debt
 665,621
 515,439

 Less: unamortized discount and deferred financing costs
 ( 14,763)
 ( 9,907)

 Total debt, net of unamortized discount and deferred financing costs
 650,858
 505,532

 Less: current maturities, net of unamortized discount and deferred financing costs
 ( 4,255)
 ( 10,956)

 Long-term debt, net of current maturities
 $
 646,603
 $
 494,576

 Annual maturities of our long-term debt for the next five years and thereafter are as follows (in thousands):

 Year Ended
 Amount Due

 2024
 $
 6,138

 2025
 6,169

 2026
 6,201

 2027
 6,234

 2028
 121,269

 Thereafter
 519,610

 Total
 $
 665,621

 As of December 31, 2023, we had $ 133.7 million in letters of credit outstanding under the ABL Credit Facility, as defined below. As of December 31, 2022, we had $ 19.5 million in letters of credit outstanding under the Prior ABL Credit Facility, as defined below. We had $ 56.2 million and $ 5.9 million in cash-collateralized letters of credit and surety bonds outstanding as of December 31, 2023 and December 31, 2022, respectively.

 Under the ABL Credit Facility and the Term Loan Credit Agreement, defined below, our subsidiaries are restricted from paying dividends or making other equity distributions, subject to certain exceptions.
 ABL Credit Facility due 2028
 On April 26, 2023, in connection with the Billings Acquisition, we repaid in full and terminated the loan and security agreements with certain lenders and Bank of America, N.A., as administrative agent and collateral agent (as amended from time to time, "Prior ABL Credit Facility") and entered into an Asset-Based Revolving Credit Agreement with certain lenders, and Wells Fargo Bank, National Association, as administrative agent and collateral agent (as amended from time to time, the "ABL Credit Facility"), providing for a senior secured asset-based revolving credit facility in an initial aggregate principal amount of up to $ 150 million and secured by a first priority lien over certain of our assets and other personal property, subject to certain customary exceptions.
 In accordance with ASC Topic 470, "Debt", we accounted for the ABL Credit Facility as a debt modification and unamortized deferred financing costs/modification costs of $ 0.7 million were rolled into the ABL Credit Facility and will be amortized over the remaining term of the ABL Credit Facility.
 On May 30, 2023, the ABL Credit Facility was amended ("ABL Credit Facility Billings Amendment") in order to, among other things, increase the commitment amount by $ 450 million, adjust the borrowing base to account for the Billings Acquisition assets, and fund an escrow account to purchase a portion of the hydrocarbon inventory associated with the Billings Acquisition. Initially the ABL Credit Facility permitted the issuance of letters of credit of up to $ 65 million; with the ABL Credit Facility Billings Amendment this amount increased to $ 250 million.
 On October 4, 2023, we entered into the Second Amendment to the ABL Credit Facility. The Second Amendment to the ABL Credit Facility provided for, among other things, (i) incremental commitments that increase the total revolver commitment under the ABL Credit Facility to $ 900 million, (ii) future incremental increases up to $ 400 million, (iii) the designation of U.S. Oil as a borrower under the ABL Credit Facility, (iv) the grant of a security interest in all or substantially all of the assets of each of U.S. Oil and certain affiliated entities' to secure the obligations under the ABL Credit Facility, and (v) amendments to certain defined terms and provisions in the ABL Credit Facility agreement. As of December 31, 2023, the ABL Credit Facility had $ 115 million outstanding in revolving loans, and a borrowing base of approximately $ 603.7 million. The ABL Credit Facility will mature, and the commitments thereunder will terminate on April 26, 2028.
 The interest rates applicable to borrowings under the ABL Credit Facility are based on a fluctuating rate of interest measured by reference to either, at our option, (i) a base rate, plus an applicable margin, or (ii) an Adjusted Term SOFR rate, plus an applicable margin. The initial applicable margin for borrowings under the ABL Credit Facility is 0.50 % per annum with respect to base rate borrowings and 1.50 % per annum with respect to SOFR borrowings, and the applicable margin for such borrowings after June 30, 2023 will be based on the our quarterly average excess availability as determined by reference to a borrowing base, ranging from 0.25 % per annum to 0.75 % per annum with respect to base rate borrowings and from 1.25 % per annum to 1.75 % per annum with respect to SOFR borrowings. We also pay a de minimis fee for any undrawn amounts available under the ABL Credit Facility. The effective interest rate was 2.65 % for the year ended December 31, 2023.
 Under the ABL Credit Agreement, the applicable margins for the ABL Credit Facility and advances under the ABL Credit Facility are as specified below:

 Level
 Arithmetic Mean of Daily Availability (as a percentage of the borrowing base)
 Term SOFR Loans
 Base Rate Loans

 >50%
 1.25 %
 0.25 %

 >30% but 50%

 1.50 %
 0.50 %

 30%

 1.75 %
 0.75 %

 The ABL Credit Facility includes certain customary affirmative and negative covenants, including a minimum financial fixed charge coverage ratio and a minimum borrower group fixed charge coverage ratio. In addition, the covenants limit our ability and the ability of our restricted subsidiaries to incur indebtedness, grant liens, make investments, engage in acquisitions, mergers, or consolidations, engage in certain hedging transactions, and pay dividends and other restricted payments.

 Term Loan Credit Agreement due 2030
 On February 28, 2023, we entered into a term loan credit agreement (the "Term Loan Credit Agreement") with Wells Fargo Bank, National Association, as administrative agent (the "Agent"), and the lenders party thereto ("Lenders"). Pursuant to the Term Loan Credit Agreement, the Lenders made an initial senior secured term loan in the principal amount of $ 550.0 million at a price equal to 98.5 % of its face value. The initial loan bears interest at SOFR, as defined below. The net proceeds were used to refinance our Term Loan B Facility and repurchase our outstanding 7.75 % Senior Secured Notes and 12.875 % Senior Secured Notes and any remaining net proceeds were used for general corporate purposes. We recognized an aggregate of $ 2.8 million in debt modification costs in connection with the refinancing, which were recorded in Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2023.
 The Term Loan Credit Agreement bears interest at a fluctuating rate per annum equal to either a SOFR rate or base rate "Base Rate", provided that the Base Rate shall not be below 1.5 %, as defined in the Term Loan Credit Agreement. The SOFR rate and Base Rate definitions are summarized below:

 SOFR Rate loan
 Secured overnight financing rate plus the applicable margin of 4.250 % per annum with a stepdown in the applicable margin of 0.25 % in the event the Company's credit rating is upgraded to Ba3/BB-,

 Base Rate loan
 A per annum rate plus the applicable margin of 3.250 %. The base rate is the greatest of:

 •
 a rate as calculated by the Federal Reserve Bank of New York based on such day's federal funds transactions by depository institutions ("Federal Funds Rate") for such day, plus 0.5 %;

 •
 a rate equal to adjusted term SOFR for a one month interest period as of such day plus 1.0 %; or

 •
 a rate as announced by Wells Fargo (the "Prime Rate").

 The Term Loan Credit Agreement requires quarterly payments of $ 1.4 million on the last business day of each March, June, September and December, commencing on June 30, 2023, with the balance due upon maturity. The Term Loan Credit Agreement matures on February 28, 2030.
 Retail Property Term Loan
 On February 23, 2021, we terminated and repaid all amounts outstanding under the Retail Property Term Loan. We recognized approximately $ 1.4 million of debt extinguishment costs related to our prepayment of the loan principal, which were recorded in Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2021. The Retail Property Term Loan bore interest based on a floating rate equal to the applicable LIBOR for a one-month interest period plus 1.5 %.
 7.75 % Senior Secured Notes
 On May 24, 2022, and July 14, 2022, we repurchased and cancelled $ 5.0 million and $ 10.0 million in aggregate principal amounts of the 7.75 % Senior Secured Notes at repurchase prices of 97.50 % and 95.00 %, respectively, of the aggregate principal amount of notes repurchased. We recognized aggregate discounts of $ 0.6 million and incurred aggregate debt extinguishment costs of $ 0.2 million for these repurchases, which were recorded in Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2022. On February 28, 2023, we repurchased and cancelled $ 260.6 million in aggregate principal amount of the 7.75 % Senior Secured Notes at a repurchase price of 102.12 % of the aggregate principal amount repurchased. On March 17, 2023, we repurchased and cancelled all remaining outstanding 7.75 % Senior Secured Notes at a repurchase price of 101.94 % of the aggregate principal amount repurchased. In connection with the termination of the 7.75 % Senior Secured Notes, we recognized debt extinguishment costs of $ 5.9 million associated with debt repurchase premiums and $ 3.4 million associated with unamortized deferred financing costs, which were recorded in Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2023. Our 7.75 % Senior Secured Notes bore interest at a rate of 7.75 % per year (payable semi-annually in arrears on June 15 and December 15 of each year, beginning on June 15, 2018).
 Term Loan B Facility
 On February 28, 2023, we terminated and repaid all amounts outstanding under the Term Loan B Facility. We recognized debt extinguishment costs of $ 1.7 million associated with unamortized deferred financing costs, which were recorded in Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2023. The Term Loan B Facility bore interest at a rate per annum equal to Adjusted LIBOR (as defined in the Term Loan B Facility) plus an applicable margin of 6.75 % or at a rate per annum equal to Alternate Base Rate (as defined in the

 Term Loan B Facility) plus an applicable margin of 5.75 %. In addition to the quarterly interest payments, the Term Loan B Facility required quarterly principal payments of $ 3.1 million.
 12.875 % Senior Secured Notes
 On June 14, 2021, we redeemed $ 36.8 million aggregate principal amount of 12.875 % Senior Secured Notes at a redemption price of 112.875 % of the aggregate principal amount of the notes redeemed, plus the accrued and unpaid interest as of the redemption date. On the redemption date, we paid a premium of approximately $ 4.7 million and incurred additional debt extinguishment costs of $ 1.9 million, which were recorded in Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2021. We repurchased and cancelled $ 13.9 million and $ 21.7 million in aggregate principal amount of 12.875 % Senior Secured Notes on May 16, 2022 and May 27, 2022, respectively, at a repurchase price of 111.25 % of the aggregate principal amount of the notes repurchased, plus accrued and unpaid interest as of the repurchase date. On June 13, 2022, we repurchased an additional $ 1.3 million in aggregate principal amount of the notes at a repurchase price of 111.00 % of the aggregate principal amount of the notes repurchased, plus accrued and unpaid interest as of the repurchase date. We paid premiums of approximately $ 4.1 million upon repurchases of the 12.875 % Senior Secured Notes during the year ended December 31, 2022 and incurred aggregate debt extinguishment costs of $ 1.6 million for these repurchases, which were recorded in Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2022. On February 28, 2023, we repurchased and cancelled $ 29 million in aggregate principal amount of the 12.875 % Senior Secured Notes at a repurchase price of 109.044 % of the aggregate principal amount repurchased. On March 17, 2023, we repurchased and cancelled all remaining outstanding 12.875 % Senior Secured Notes at a repurchase price of 108.616 % of the aggregate principal amount repurchased. In connection with the termination of the 12.875 % Senior Secured Notes, we recognized debt extinguishment costs of $ 2.8 million associated with debt repurchase premiums and $ 1.1 million associated with unamortized deferred financing costs, which were recorded in Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2023. The 12.875 % Senior Secured Notes bore interest at an annual rate of 12.875 % per year (payable semi-annually in arrears on January 15 and July 15 of each year, beginning on January 15, 2021).
 Other long-term debt
 On June 7, 2023, we entered into two promissory notes with a third-party lender to acquire land in Kahului, Hawaii, and Hilo, Hawaii totaling $ 5.1 million. The notes bear interest at a fixed rate of 4.625 % per annum and are payable on the first day of each month, commencing on July 1, 2023, until maturity. The promissory notes are unsecured and mature on June 7, 2030.
 Cross Default Provisions
 Included within each of our debt agreements are affirmative and negative covenants and customary cross default provisions that require the repayment of amounts outstanding on demand unless the triggering payment default or acceleration is remedied, rescinded, or waived. As of December 31, 2023, we were in compliance with all of our debt instruments.
 Guarantors
 In connection with our shelf registration statement on Form S-3, which was filed with the Securities and Exchange Commission ("SEC") and declared effective on February 14, 2022 ("Registration Statement"), we may sell non-convertible debt securities and other securities in one or more offerings with an aggregate initial offering price of up to $ 750.0 million. Any non-convertible debt securities issued under the Registration Statement may be fully and unconditionally guaranteed (except for customary release provisions), on a joint and several basis, by some or all of our subsidiaries, other than subsidiaries that are "minor" within the meaning of Rule 3-10 of Regulation S-X (the "Guarantor Subsidiaries"). We have no "independent assets or operations" within the meaning of Rule 3-10 of Regulation S-X and certain of the Guarantor Subsidiaries may be subject to restrictions on their ability to distribute funds to us, whether by cash dividends, loans, or advances.

 Note 15— Derivatives
 Commodity Derivatives
 We utilize commodity derivative contracts to manage our price exposure in our inventory positions, future purchases of crude oil, future purchases and sales of refined products, and crude oil consumption in our refining process. The derivative contracts that we execute to manage our price risk include exchange traded futures, options, and OTC swaps. Our futures, options, and OTC swaps are marked-to-market and changes in the fair value of these contracts are recognized within Cost of revenues (excluding depreciation) on our consolidated statements of operations.
 We are obligated to repurchase the crude oil and refined products from J. Aron at the termination of the Supply and Offtake Agreement. Our Washington Refinery Intermediation Agreement contained forward purchase obligations for certain volumes of crude oil and refined products that are required to be settled at market prices on a monthly basis. We have determined that these obligations under the Supply and Offtake Agreement contain embedded derivatives. As such, we have accounted for these embedded derivatives at fair value with changes in the fair value recorded in Cost of revenues (excluding depreciation) on our consolidated statements of operations.
 We have entered into forward purchase contracts for crude oil and forward purchases and sales contracts of refined products. We elect the normal purchases normal sales ("NPNS") exception for all forward contracts that meet the definition of a derivative and are not expected to net settle. Any gains and losses with respect to these forward contracts designated as NPNS are not reflected in earnings until the delivery occurs.
 We elect to offset fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement. Our consolidated balance sheets present derivative assets and liabilities on a net basis. Please read Note 16—Fair Value Measurements for the gross fair value and net carrying value of our derivative instruments. Our cash margin that is required as collateral deposits cannot be offset against the fair value of open contracts except in the event of default.
 Our open futures and OTC swaps expire in March 2025. At December 31, 2023, our open commodity derivative contracts represented (in thousands of barrels):

 Contract type
 Purchases
 Sales
 Net

 Futures
 27,604
 ( 28,104)
 ( 500)

 Swaps
 36,051
 ( 41,790)
 ( 5,739)

 Total
 63,655
 ( 69,894)
 ( 6,239)

 At December 31, 2023, we also had option collars that economically hedge a portion of our internally consumed fuel at our refineries. The following table provides information on these option collars at our refineries as of December 31, 2023:

 Total open option collars

 1,394

 Weighted-average strike price - floor (in dollars)
 $
 61.69

 Weighted-average strike price - ceiling (in dollars)
 $
 82.97

 Earliest commencement date

 January 2024

 Furthest expiry date

 September 2024

 Interest Rate Derivatives
 We are exposed to interest rate volatility in our ABL Credit Facility, LC Facility, Term Loan Credit Agreement, and the Supply and Offtake Agreement. We may utilize interest rate swaps to manage our interest rate risk. On April 12, 2023, we entered into an interest rate collar transaction to manage our interest rate risk related to the Term Loan Credit Agreement. The interest rate collar agreement reduces variable interest rate risk from May 31, 2023, through May 31, 2026, with a notional amount of $ 300.0 million as of December 31, 2023. The terms of the agreement provide for an interest rate cap of 5.50 % and floor of 2.30 %, based on the three month SOFR as of the fixing date. We pay variable interest quarterly until the three month SOFR reaches the floor. If the three month SOFR is between the floor and the cap, no payment is due to either party. If the three month SOFR is greater than the cap, the counterparty pays us. The interest rate collar transaction expires on May 31, 2026. As of December 31, 2022, we did not hold any interest rate derivative instruments.

 As of December 31, 2020, we had entered into an interest rate swap at an average fixed rate of 3.91 % in exchange for the floating interest rate on the notional amounts due under the Retail Property Term Loan. This swap was set to expire on May 31, 2026, the maturity date of the Retail Property Term Loan. On February 23, 2021, we terminated and repaid all amounts outstanding under the Retail Property Term Loan and the related interest rate swap.
 The following table provides information on the fair value amounts (in thousands) of these derivatives as of December 31, 2023 and 2022 and their placement within our consolidated balance sheets.

 Balance Sheet Location
 2023
 2022

 Asset (Liability)

 Commodity derivatives (1)
 $
 43,356
 $

 Commodity derivatives (2)

 ( 530)
 ( 10,989)

 J. Aron repurchase obligation derivative
 ( 12,156)

 MLC terminal obligation derivative
 —
 14,435

 Interest rate derivatives
 Other liabilities
 —

 (1)Does not include cash collateral of $ 21.8 million and $ 40.8 million recorded in Prepaid and other current assets as of December 31, 2023, and December 31, 2022, respectively, and $ 9.5 million in Other long-term assets as of both December 31, 2023 and December 31, 2022.
 (2)Does not include $ 27.2 million recorded in Other accrued liabilities as of December 31, 2023 related to realized derivatives payable.
 The following table summarizes the pre-tax gains (losses) recognized in Net income (loss) on our consolidated statements of operations resulting from changes in fair value of derivative instruments not designated as hedges charged directly to earnings (in thousands):

 Statement of Operations Classification
 2023
 2022
 2021

 $
 ( 16,701)
 $
 ( 65,814)
 $
 ( 22,417)

 J. Aron repurchase obligation derivative
 11,764
 2,995
 5,646

 MLC terminal obligation derivative
 ( 34,149)
 ( 49,636)
 ( 73,256)

 Interest rate derivatives
 —

 Note 16— Fair Value Measurements
 Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
 Purchase Price Allocation of Billings Acquisition
 The preliminary fair values of the assets acquired and liabilities assumed as a result of the Billings Acquisition were estimated as of June 1, 2023, the date of the acquisition, using valuation techniques described in notes (1) through (5) below.

 Valuation

 Fair Value
 Technique

 Net working capital excluding operating leases
 $
 294,507
 (1)

 259,088
 (2)

 Operating lease right-of-use assets
 3,562
 (3)

 Refining and logistics equity investments
 86,600
 (4)

 4,094
 (1)

 Current operating lease liabilities
 ( 2,081)
 (3)

 Long-term operating lease liabilities
 ( 1,481)
 (3)

 Environmental liabilities
 ( 18,869)
 (5)

 Total
 $
 625,420

 (1)Current assets acquired and liabilities assumed were recorded at their net realizable value. Other long-term assets includes preliminary costs for future turnarounds that were recently incurred and were recorded at their fair value.
 (2)The fair value of personal property was estimated using the cost approach. Key assumptions in the cost approach include determining the replacement cost by evaluating recent purchases of comparable assets or published data, and adjusting replacement cost for economic and functional obsolescence, location, normal useful lives, and capacity (if applicable). The fair value of real property was estimated using the market approach. Key assumptions in the market approach include determining the asset value by evaluating recent purchases of comparable assets under similar circumstances. We consider this to be a Level 3 fair value measurement.
 (3)Operating lease right-of-use assets and liabilities were recognized based on the present value of lease payments over the lease term using the incremental borrowing rate at acquisition of 9.6 %.
 (4)The fair value of our investments in YELP and YPLC were determined using a combination of the income approach and the market approach. Under the income approach, we estimated the present value of expected future cash flows using a market participant discount rate. Under the market approach, we estimated fair value using observable multiples for comparable companies in the investments' industries. These valuation methods require us to make significant estimates and assumptions regarding future cash flows, capital projects, commodity prices, long-term growth rates, and discount rates. We consider this to be a Level 3 fair value measurement.
 (5)Environmental liabilities are based on management's best estimates of probable future costs using currently available information. We consider this to be a Level 3 fair value measurement.
 Equity Method Investments
 We evaluate equity method investments for impairment when factors indicate that a decrease in the value of our investment has occurred and the carrying amount of our investment may not be recoverable. An impairment loss, based on the difference between the carrying value and the estimated fair value of the investment, is recognized in earnings when an impairment is deemed to be other than temporary.
 Par West Refinery
 Pursuant to GAAP accounting guidelines, the Par West refinery was deemed abandoned in the fourth quarter of 2020 due to the following factors: the idling of the assets for more than an insignificant amount of time, the significant cost to restart the refinery, and a lack of a current plan or timeline to restart the refinery. Given the lack of alternative uses of the Par West refinery assets, we impaired all assets that are not expected to be used as part of our ongoing refining operations in Hawaii

 down to their salvage value, which is immaterial. For the year ended December 31, 2021, we recorded $ 0.2 million of Impairment expense on our consolidated statement of operations related to this idling.
 Assets and Liabilities Measured at Fair Value on a Recurring Basis
 Derivative instruments
 We classify financial assets and liabilities according to the fair value hierarchy. Financial assets and liabilities classified as Level 1 instruments are valued using quoted prices in active markets for identical assets and liabilities. These include our exchange traded futures. Level 2 instruments are valued using quoted prices for similar assets and liabilities in active markets and inputs other than quoted prices that are observable for the asset or liability. Our Level 2 instruments include OTC swaps and options. These derivatives are valued using market quotations from independent price reporting agencies and commodity exchange price curves that are corroborated with market data. Level 3 instruments are valued using significant unobservable inputs that are not supported by sufficient market activity. The valuation of the embedded derivatives related to our J. Aron repurchase obligation is based on estimates of the prices and differentials assuming settlement at the end of the reporting period. Estimates of the J. Aron settlement prices are based on observable inputs, such as Brent indices, and unobservable inputs, such as contractual price differentials as defined in the Supply and Offtake Agreement. Such contractual differentials vary by location and by the type of product, have a weighted average of $ 13.75 per barrel, and range from a discount of $ 7.74 per barrel to a premium of $ 36.07 per barrel as of December 31, 2023. Contractual price differentials are considered unobservable inputs; therefore, these embedded derivatives are classified as Level 3 instruments. We do not have other commodity derivatives classified as Level 3 at December 31, 2023 or 2022. Please read Note 15—Derivatives for further information on derivatives.
 Gross Environmental credit obligations
 During the quarter ended December 31, 2023, we had a change in estimate in our valuation of our gross environmental credit obligations, due to the settlement of all outstanding prior period environmental credit obligations. Beginning in the fourth quarter of 2023, the portion of the estimated gross environmental credit obligations satisfied by internally generated or purchased RINs or other environmental credits is recorded at the carrying value of such internally generated or purchased RINs or other environmental credits. The remainder of the estimated gross environmental credit obligation is recorded at the market price of the RINs or other environmental credits that are needed to satisfy the remaining obligation as of the end of the reporting period and classified as Level 2 instruments as we obtain the pricing inputs for the RINs and other environmental credits from brokers based on market quotes on similar instruments. Please read Note 18—Commitments and Contingencies for further information on the EPA regulations related to greenhouse gases and our environmental credit obligations.
 Financial Statement Impact
 Fair value amounts by hierarchy level as of December 31, 2023 and 2022 are presented gross in the tables below (in thousands):

 Level 1
 Level 2
 Level 3
 Gross Fair Value
 Effect of Counter-party Netting
 Net Carrying Value on Balance Sheet (1)

 Assets

 $
 100,074
 $
 175,191
 $
 —
 $
 275,265
 $
 ( 231,909)
 $
 43,356

 Liabilities

 $
 ( 92,417)
 $
 ( 140,022)
 $
 —
 $
 ( 232,439)
 $
 231,909
 $
 ( 530)

 J. Aron repurchase obligation derivative
 —
 —
 —

 Interest rate derivatives (3)
 —
 —
 —

 Gross environmental credit obligations (2), (3)

 —
 ( 54,245)
 —
 ( 54,245)
 —
 ( 54,245)

 Total

 $
 ( 92,417)
 $
 ( 195,088)
 $
 $
 ( 287,897)
 $
 231,909
 $
 ( 55,988)

 Level 1
 Level 2
 Level 3
 Gross Fair Value
 Effect of Counter-party Netting
 Net Carrying Value on Balance Sheet (1)

 Assets

 $
 161,541
 $
 8,369
 $
 —
 $
 169,910
 $
 ( 169,415)
 $

 Liabilities

 $
 ( 172,529)
 $
 ( 7,875)
 $
 —
 $
 ( 180,404)
 $
 169,415
 $
 ( 10,989)

 J. Aron repurchase obligation derivative
 —
 —
 ( 12,156)
 ( 12,156)
 —
 ( 12,156)

 MLC terminal obligation derivative
 —
 —
 14,435
 14,435
 —
 14,435

 Gross environmental credit obligations (2)
 —
 ( 549,791)
 —
 ( 549,791)
 —
 ( 549,791)

 Total

 $
 ( 172,529)
 $
 ( 557,666)
 $
 2,279
 $
 ( 727,916)
 $
 169,415
 $
 ( 558,501)

 (1)Does not include cash collateral of $ 31.3 million and $ 50.3 million as of December 31, 2023 and 2022, respectively, included within Prepaid and other current assets and Other long-term assets on our consolidated balance sheets.
 (2)Does not include RINs assets and other environmental credits of $ 237.6 million and $ 258.2 million presented as Inventories on our consolidated balance sheet and stated at the lower of cost and net realizable value as of December 31, 2023 and 2022, respectively.
 (3)Does not include environmental liabilities of $ 232.7 million, satisfied by internally generated or purchased environmental credits and presented at the carrying value of these credits. included in Other accrued liabilities on our consolidated balance sheets as of December 31, 2023.
 A roll forward of Level 3 derivative instruments measured at fair value on a recurring basis is as follows (in thousands):

 2023
 2022
 2021

 Balance, beginning of period
 $
 2,279
 $
 ( 37,321)
 $
 ( 30,958)

 Settlements
 19,714
 86,242
 61,247

 Total gains (losses) included in earnings (1)
 ( 22,385)
 ( 46,642)
 ( 67,610)

 Balance, end of period
 $
 $
 2,279
 $
 ( 37,321)

 (1)Included in Cost of revenues (excluding depreciation) on our consolidated statements of operations.
 The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2023 and 2022 are as follows (in thousands):

 Carrying Value
 Fair Value

 ABL Credit Facility due 2028 (2)

 $
 115,000
 $
 115,000

 LC Facility due 2024 (2)

 —
 —

 Term Loan Credit Agreement due 2030 (1)

 531,112
 545,875

 Other long-term debt (1)
 4,746
 4,387

 Carrying Value
 Fair Value

 Prior ABL Credit Facility due 2025 (2)

 $
 —
 $
 —

 7.75 % Senior Secured Notes due 2025 (1) (3)

 277,137
 276,785

 Term Loan B Facility due 2026 (1) (3)

 198,268
 201,094

 12.875 % Senior Secured Notes due 2026 (1) (3)

 30,127
 34,029

 (1)The fair value measurements of the Term Loan Credit Agreement, Other long-term debt, 7.75 % Senior Secured Notes, Term Loan B Facility, and 12.875 % Senior Secured Notes are considered Level 2 measurements in the fair value hierarchy as discussed below.
 (2)The fair value measurements of the ABL Credit Facility, LC Facility, and the Prior ABL Credit Facility are considered Level 3 measurements in the fair value hierarchy.
 (3)The 7.75 % Senior Secured Notes, Term Loan B Facility, and 12.875 % Senior Secured Notes were fully repaid in 2023, please read Note 14—Debt for more information.
 The fair value of the Term Loan Credit Agreement, Other long-term debt, 7.75 % Senior Secured Notes, Term Loan B Facility, and 12.875 % Senior Secured Notes were determined using a market approach based on quoted prices. The inputs used to measure the fair value are classified as Level 2 inputs within the fair value hierarchy because the Term Loan Credit Agreement, Other long-term debt, 7.75 % Senior Secured Notes, Term Loan B Facility, and 12.875 % Senior Secured Notes may not be actively traded.
 The carrying value of our ABL Credit Facility was determined to approximate fair value as of December 31, 2023. The fair value of all non-derivative financial instruments recorded in current assets, including cash and cash equivalents, restricted cash, and trade accounts receivable, and current liabilities, including accounts payable, approximated their carrying value due to their short-term nature.

 Note 17— Leases
 We have cancellable and non-cancellable finance and operating lease liabilities for the lease of land, vehicles, office space, retail facilities, and other facilities used in the storage and transportation of crude oil and refined products. Most of our leases include one or more options to renew, with renewal terms that can extend the lease term from one to 30 years or more. There are no material residual value guarantees associated with any of our leases.

 The following table provides information on the amounts (in thousands, except lease term and discount rates) of our ROU assets and liabilities as of December 31, 2023 and 2022 and their placement within our consolidated balance sheets:

 Lease type
 Balance Sheet Location

 Assets

 $
 28,264
 $
 21,150

 Accumulated amortization
 ( 12,212)
 ( 10,308)

 16,052
 10,842

 Operating lease right-of-use assets
 346,454
 350,761

 Total right-of-use assets
 $
 362,506
 $
 361,603

 Liabilities

 Current

 $
 1,820
 $
 1,782

 72,833
 66,081

 Long-term

 Finance lease liabilities
 12,438
 6,311

 282,517
 292,701

 Total lease liabilities
 $
 369,608
 $
 366,875

 Weighted-average remaining lease term (in years)

 11.02
 5.60

 8.67
 9.00

 Weighted-average discount rate

 8.04
 %
 7.38
 %

 7.24
 %
 7.10
 %

 The following table summarizes the lease costs recognized in our consolidated statements of operations (in thousands):

 Lease cost type
 2023
 2022
 2021

 Finance lease cost

 Amortization of finance lease ROU assets
 $
 1,906
 $
 1,917
 $
 1,913

 Interest on lease liabilities

 Operating lease cost
 98,928
 89,591
 91,882

 Variable lease cost
 9,246
 5,478
 6,716

 Short-term lease cost
 13,500
 8,575
 1,013

 Net lease cost
 $
 124,216
 $
 106,180
 $
 102,179

 Operating lease income (1)
 $
 ( 14,908)
 $
 ( 11,030)
 $
 ( 3,149)

 (1)At December 31, 2023 and 2022, Property, plant, and equipment, net associated with leased assets was approximately $ 9.5 million and $ 9.2 million, respectively. The majority of our lessor income comes from leases with lease terms of one year or less and the estimated future undiscounted cash flows from lessor income are not expected to be material.

 The following table summarizes the supplemental cash flow information related to leases as follows (in thousands):

 Lease type
 2023
 2022
 2021

 Cash paid for amounts included in the measurement of liabilities

 Financing cash flows from finance leases
 $
 1,693
 $
 1,620
 $
 1,914

 Operating cash flows from finance leases

 Operating cash flows from operating leases
 98,416
 85,681
 89,677

 Non-cash supplemental amounts

 ROU assets obtained in exchange for new finance lease liabilities
 7,896
 1,936

 ROU assets obtained in exchange for new operating lease liabilities
 72,219
 64,567
 97,011

 ROU assets terminated in exchange for release from finance lease liabilities
 —
 —
 —

 ROU assets terminated in exchange for release from operating lease liabilities
 1,439
 32,902
 6,847

 The table below includes the estimated future undiscounted cash flows for finance and operating leases as of December 31, 2023 (in thousands):

 For the year ending December 31,
 Finance leases
 Operating leases
 Total

 2024
 $
 3,414
 $
 93,583
 $
 96,997

 2025
 2,668
 63,897
 66,565

 2026
 2,222
 57,383
 59,605

 2027
 2,027
 56,067
 58,094

 2028
 1,206
 52,023
 53,229

 Thereafter
 9,856
 134,526
 144,382

 Total lease payments
 21,393
 457,479
 478,872

 Less amount representing interest
 ( 7,135)
 ( 102,129)
 ( 109,264)

 Present value of lease liabilities
 $
 14,258
 $
 355,350
 $
 369,608

 Additionally, we have $ 22.5 million in future undiscounted cash flows for operating leases and no future undiscounted cash flows for finance leases that have not yet commenced. These leases are expected to commence when the lessor has made the equipment or location available to us to operate or begin construction, respectively.
 Sale-Leaseback Transaction
 On February 11, 2021, Par Hawaii, LLC ("PHL") and Par Hawaii Property Company, LLC (collectively, the "Sellers"), both our wholly owned subsidiaries, entered into a Purchase Agreement and Escrow Instructions with MDC Coast HI 1, LLC, a subsidiary of Realty Income Corporation (the "Buyer"), and Fidelity National Title Insurance Company, pursuant to which the Sellers and Buyer agreed to consummate a sale-leaseback transaction (the "Sale-Leaseback Transactions"). Under the terms of the Purchase Agreement, the Sellers agreed to sell to the Buyer a total of twenty-two ( 22) retail convenience store/fuel station properties located in Hawaii (the "Sale-Leaseback Properties") for an aggregate cash purchase price of $ 112.8 million, net of transaction fees.
 On February 23, 2021, the Sellers and Buyer closed the Sale-Leaseback Transactions with respect to twenty-one ( 21) Sale-Leaseback Properties for an aggregate cash purchase price of approximately $ 107.0 million, net of transaction fees. On March 12, 2021, the Sellers and Buyer closed the sale of one additional property for an aggregate cash purchase price of approximately $ 5.8 million, net of transaction fees. We recognized a gain of $ 63.9 million as a result of these transactions, which is included in Loss (gain) on sale of assets, net on our consolidated statements of operations for the year ended December 31, 2021.
 Upon the closings of the sales of the Sale-Leaseback Properties, PHL entered into a Master Land and Building Lease Agreement (the "Lease Agreement") with the Buyer, pursuant to which, among other things, PHL leased the Sale-Leaseback Properties from the Buyer, on a commercial triple-net basis, for 15 years unless earlier terminated. The initial lease term may be

 extended for up to four five-year renewal terms in accordance with the terms of the Lease Agreement. Under the terms of the Lease Agreement, PHL is responsible for monthly rent and all expenses related to the leased facilities, including, but not limited to, insurance premiums, taxes, and other expenses, such as utilities. As a result of the Sale-Leaseback Transactions, we recorded operating ROU assets and lease liabilities of $ 81.3 million. Certain of the Sale-Leaseback Properties were treated as failed sale-leaseback transactions based on the terms of the lease. As such, we retained the book value of the assets and recognized a finance liability of $ 12.4 million included in Other accrued liabilities and Other liabilities on our consolidated balance sheet.
 In connection with PHL's entry into the Lease Agreement, Par Petroleum, LLC, our wholly owned subsidiary, entered into a guaranty agreement in favor of the Buyer, pursuant to which, among other things, Par Petroleum, LLC guaranteed the payment when due of the monthly rent, and all other additional rent, interest, and charges payable by PHL to the Buyer under the Lease Agreement, and the performance by PHL of all the material terms, conditions, covenants, and agreements of the Lease Agreement.

 Note 18— Commitments and Contingencies
 In the ordinary course of business, we are a party to various lawsuits and other contingent matters. We establish accruals for specific legal matters when we determine that the likelihood of an unfavorable outcome is probable and the loss is reasonably estimable. It is possible that an unfavorable outcome of one or more of these lawsuits or other contingencies could have a material impact on our financial condition, results of operations, or cash flows.
 Tax and Related Matters
 We are also party to various other legal proceedings, claims, and regulatory, tax or government audits, inquiries and investigations that arise in the ordinary course of business. From time to time, Par Hawaii Refining, LLC has appealed various tax assessments related to its land, buildings, and fuel storage tanks, and is currently appealing the City of Honolulu's property tax assessment for tax year 2023. During the first quarter of 2022, we received a tax assessment in the amount of $ 1.4 million from the Washington Department of Revenue related to its audit of certain taxes allegedly payable on certain sales of raw vacuum gas oil between 2014 and 2016. We believe the Department of Revenue's interpretation is in conflict with its prior guidance and we appealed in November 2022. By opinion dated September 22, 2021, the Hawaii Attorney General reversed a prior 1964 opinion exempting various business transactions conducted in Hawaii foreign trade zone from certain state taxes. We and other similarly situated state taxpayers who had previously claimed such exemptions, certain of which we are contractually obligated to indemnify, are currently being audited for such prior tax periods. Similarly, on September 30, 2021, we received notice of a complaint filed on May 17, 2021, on camera and under seal in the first circuit court of the state of Hawaii alleging that Par Hawaii Refining, LLC, Par Pacific Holdings, Inc. and certain unnamed defendants made false claims and statements in connection with various state tax returns related to our business conducted within the Hawaii foreign trade zone, and seeking unspecified damages, penalties, interest and injunctive relief. We dispute the allegations in the complaint and intend to vigorously defend ourselves in such proceeding. We believe the likelihood of an unfavorable outcome in these matters to be neither probable nor reasonably estimable.
 Environmental Matters
 Like other petroleum refiners, our operations are subject to extensive and periodically-changing federal, state, and local environmental laws and regulations governing air emissions, wastewater discharges, and solid and hazardous waste management activities. Many of these regulations are becoming increasingly stringent and the cost of compliance can be expected to increase over time.
 Periodically, we receive communications from various federal, state, and local governmental authorities asserting violations of environmental laws and/or regulations. These governmental entities may also propose or assess fines or require corrective actions for these asserted violations. Except as disclosed below, we do not anticipate that any such matters currently asserted will have a material impact on our financial condition, results of operations, or cash flows.
 Hawaii Consent Decree
 On July 18, 2016, PHR and subsidiaries of Tesoro Corporation ("Tesoro") entered into a consent decree with the EPA, the U.S. Department of Justice and other state governmental authorities concerning alleged violations of the federal Clean Air Act related to the ownership and operation of multiple facilities owned or formerly owned by Tesoro and its affiliates ("Consent Decree"), including our refinery in Kapolei, Hawaii, that we acquired from Tesoro in 2013. On September 29, 2023, we received a letter from EPA related to the alleged violation of certain air emissions limits, controls, monitoring, and repair

 requirements under the Consent Decree. We are unable to predict the cost to resolve these alleged violations, but resolution will likely involve financial penalties or impose capital expenditure requirements that could be material.
 Wyoming Refinery
 Our Wyoming refinery is subject to a number of consent decrees, orders, and settlement agreements involving the EPA and/or the Wyoming Department of Environmental Quality, some of which date back to the late 1970s and several of which remain in effect, requiring further actions at the Wyoming refinery. The largest cost component arising from these various decrees relates to the investigation, monitoring, and remediation of soil, groundwater, surface water and sediment contamination associated with the facility's historic operations. Investigative work by Hermes Consolidated LLC, and its wholly owned subsidiary, Wyoming Pipeline Company (collectively, "WRC" or "Wyoming Refining") and negotiations with the relevant agencies as to remedial approaches remain ongoing on a number of aspects of the contamination, meaning that investigation, monitoring, and remediation costs are not reasonably estimable for some elements of these efforts. As of December 31, 2023, we have accrued $ 14.0 million for the well-understood components of these efforts based on current information, approximately one-third of which we expect to incur in the next five years and the remainder to be incurred over approximately 30 years.
 Additionally, we believe the Wyoming refinery will need to modify or close a series of wastewater impoundments in the next several years and replace those impoundments with a new wastewater treatment system. Based on current information, reasonable estimates we have received suggest costs of approximately $ 11.6 million to design and construct a new wastewater treatment system.
 Finally, among the various historic consent decrees, orders, and settlement agreements into which Wyoming Refining has entered, there are several penalty orders associated with exceedances of permitted limits by the Wyoming refinery's wastewater discharges. Although the frequency of these exceedances has declined over time, Wyoming Refining may become subject to new penalty enforcement action in the next several years, which could involve penalties in excess of $ 300,000.
 Washington Climate Commitment Act and Clean Fuel Standard
 In 2021, the Washington legislature passed the Climate Commitment Act ("Washington CCA"), which established a cap and invest program designed to significantly reduce greenhouse gas emissions. Rules implementing the Washington CCA by the Washington Department of Ecology set a cap on greenhouse gas emissions, provide mechanisms for the sale and tracking of tradable emissions allowances, and establish additional compliance and accountability measures. The Washington CCA became effective in January 2023 and the first auction for emissions allowances took place in February 2023. Additionally, a low carbon fuel standard (the "Clean Fuel Standard") that limits carbon in transportation fuels and enables certain producers to buy or sell credits was also signed into law and became effective in 2023. We will be required to purchase compliance credits or allowances if we are unable to reduce emissions at our Tacoma refinery or reduce the amount of carbon in the transportation fuels we sell in Washington, which could have a material impact on our financial condition, results of operations, or cash flows. During the third quarter of 2023, we received and responded to a civil investigative demand for information related to our compliance with the Washington CCA.
 Regulation of Greenhouse Gases
 Under the Energy Independence and Security Act (the "EISA"), the Renewable Fuel Standard (the "RFS") requires an increasing amount of renewable fuel to be blended into the nation's transportation fuel supply. Over time, higher annual RFS requirements have the potential to reduce demand for our refined transportation fuel products. In the near term, the RFS will be satisfied primarily with fuel ethanol blended into gasoline or by purchasing renewable credits, referred to as RINs, to maintain compliance. During the year ended December 31, 2023, we settled all of our 2020, 2021, and 2022 RVO liabilities, which resulted in a gain of $ 102.1 million associated with the difference between the carrying value of the RINs retired and the market value of the RVO settled. This gain is included in Cost of revenues (excluding depreciation) on our consolidated statements of operations.
 The RFS may present production and logistics challenges for both the renewable fuels and petroleum refining and marketing industries in that we may have to enter into arrangements with other parties or purchase D3 waivers from the EPA to meet our obligations to use advanced biofuels, including biomass-based diesel and cellulosic biofuel, with potentially uncertain supplies of these new fuels.
 There will be compliance costs and uncertainties regarding how we will comply with the various requirements contained in the EISA, RFS, and other fuel-related regulations. We may experience a decrease in demand for refined petroleum products due to an increase in combined fleet mileage or due to refined petroleum products being replaced by renewable fuels.

 Environmental Agreement
 On September 25, 2013, Par Petroleum, LLC (formerly Hawaii Pacific Energy, a wholly owned subsidiary of Par created for purposes of the acquisition of PHR), Tesoro Corporation ("Tesoro"), and PHR entered into an Environmental Agreement ("Environmental Agreement") that allocated responsibility for known and contingent environmental liabilities related to the acquisition of PHR, including a consent decree.
 Indemnification
 In addition to its obligation to reimburse us for capital expenditures incurred pursuant to a consent decree, Tesoro agreed to indemnify us for claims and losses arising out of related breaches of Tesoro's representations, warranties, and covenants in the Environmental Agreement, certain defined "corrective actions" relating to pre-existing environmental conditions, third-party claims arising under environmental laws for personal injury or property damage arising out of or relating to releases of hazardous materials that occurred prior to the date of the closing of the PHR acquisition, any fine, penalty, or other cost assessed by a governmental authority in connection with violations of environmental laws by PHR prior to the date of the closing of the PHR acquisition, certain groundwater remediation work, fines, or penalties imposed on PHR by a consent decree related to acts or omissions of Tesoro prior to the date of the closing of the PHR acquisition, and claims and losses related to the Pearl City Superfund Site.
 Tesoro's indemnification obligations are subject to certain limitations as set forth in the Environmental Agreement. These limitations include a deductible of $ 1 million and a cap of $ 15 million for certain of Tesoro's indemnification obligations related to certain pre-existing conditions, as well as certain restrictions regarding the time limits for submitting notice and supporting documentation for remediation actions.
 Major Customers
 We sell a variety of refined products to a diverse customer base. For each of the years ended December 31, 2023, 2022, and 2021, we had one customer in our refining segment that accounted for 13 %, 17 %, and, 13 %, respectively, of our consolidated revenue. No other customer accounted for more than 10% of our consolidated revenues during the years ended December 31, 2023, 2022, and 2021.

 Note 19— Stockholders' Equity
 Common Stock
 Our certificate of incorporation contains restrictions on the transfer of certain of our securities in order to preserve the net operating loss carryovers, capital loss carryovers, general business credit carryovers, and foreign tax credit carryovers, as well as any "net unrealized built-in loss" within the meaning of Section 382 of the Internal Revenue Service Code, of us or any direct or indirect subsidiary thereof. These restrictions include provisions regarding approval by our Board of Directors of transfers of common stock by holders of five percent or more of the outstanding common stock. Our debt agreements restrict the payment of dividends.
 Issuance of Common Stock
 On March 16, 2021, we entered into an underwriting agreement with J.P. Morgan Securities LLC and Goldman Sachs & Co. LLC, as representatives of the several underwriters named therein, in connection with an underwritten public offering (the "Equity Offering") of 5.75 million shares of common stock, par value $ 0.01 per share, at a public offering price of $ 16.00 per share. We completed the issuance of these shares on March 19, 2021. The net proceeds from the Equity Offering were approximately $ 87.2 million, after deducting underwriting discounts and commissions and offering expenses. We used the net proceeds from the Equity Offering to repay the remaining $ 48.7 million in aggregate 5.00 % Convertible Senior Notes due at maturity in June 2021 and $ 36.8 million in aggregate principal amount of 12.875 % Senior Secured Notes, and the remainder for general corporate purposes, including capital expenditures and funding working capital.
 Share Repurchase Program
 On November 10, 2021, the Board authorized and approved a share repurchase program for up to $ 50 million of the currently outstanding shares of the Company's common stock with no specified end date. On August 2, 2023, the Board approved expanding the Company's share repurchase authorization from $ 50 million to $ 250 million. Under the share repurchase program, the Company may repurchase shares through open market purchases, privately negotiated transactions, block purchases, or otherwise in accordance with applicable federal and state laws. The share repurchase program does not have

 a specified end date and may be limited or terminated at any time without prior notice. During the years ended December 31, 2023 and 2022, 1,841 thousand and 420 thousand shares were repurchased under this share repurchase program for a total of $ 62.1 million and $ 5.8 million, respectively. The repurchased shares were retired by the Company upon receipt. As of December 31, 2023, there was $ 181.8 million of authorization remaining under this share repurchase program.
 Incentive Plans
 Our incentive compensation plans are described below.
 Long Term Incentive Plan
 Under the Par Petroleum Corporation 2012 Long Term Incentive Plan ("Incentive Plan" or "LTIP"), as amended and restated, the Board, or a committee of the Board, may grant incentive stock options, nonstatutory stock options, restricted stock, restricted stock units, and performance restricted stock units to directors and other employees or those of our subsidiaries. The maximum number of shares that may be granted under the LTIP is 9.0 million shares of common stock. At December 31, 2023, 3.0 million shares were available for future grants and awards under the LTIP.
 Restricted stock and restricted stock units awarded under the Incentive Plan are subject to restrictions, terms, and conditions, including forfeitures, as may be determined by the Board. During the period in which such restrictions apply, unless specifically provided otherwise in accordance with the terms of the Incentive Plan, the recipient of the restricted stock would be the record owner of the shares and have all of the rights of a stockholder with respect to the shares, including the right to vote and the right to receive dividends or other distributions made or paid with respect to the shares. The recipient of restricted stock units shall not have any of the rights of a stockholder of the Company until such units vest and convert into shares of common stock. The fair value of the restricted stock and stock units is generally determined based upon the quoted market price of our common stock on the date of grant. Restricted stock awards generally vest ratably over a four-year period. Restricted stock units do not vest ratably, rather they generally vest in full at the end of three years, while some restricted stock units vest over the same period of time with a one-year cliff.
 Stock options are issued with an exercise price equal to the fair market value of our common stock on the date of grant and are subject to such other terms and conditions as may be determined by the Board. The options generally expire eight years from the grant date, unless granted by the Board for a shorter term. Option grants generally vest ratably over a four-year period.
 Stock Purchase Plan
 The Stock Purchase Plan (as amended, the "SPP") is limited to the Company's qualifying executive officers and directors who qualify as accredited investors under Rule 501(a) of the Securities Act of 1933, as amended. The SPP provides that each participant may, subject to compliance with securities laws and other regulations and only during "window periods" as described in our insider trading policy as in effect from time to time, until the later to occur of (a) December 31, 2015 or (b) the eighteen month anniversary of the date that the participant commenced his or her employment or service with us, purchase, in a single transaction, up to $ 1 million of shares of our common stock ("the SPP Shares") at a per share purchase price equal to the closing price of the common stock on the date of purchase. The sale or transfer of the SPP Shares by such participant would be limited for the earlier of (i) two years from the date of purchase or (ii) the termination of the participant's service with us or any affiliates for any reason. Additionally, the SPP provides that each purchasing participant will be granted a number of shares of restricted common stock under the Incentive Plan equal to 20 % of the SPP Shares purchased with 50 % of the restricted common stock vesting on each of the two annual anniversaries of the date of grant. Each purchasing participant will also be granted nonstatutory stock options with a 5-year term to purchase a number of shares of common stock under the Incentive Plan (with an exercise price equal to the Fair Market Value as defined in the Incentive Plan on the date of grant) equal to certain specified percentages of the SPP Shares purchased based on a Black-Scholes model with 50 % of the options vesting on each of the two annual anniversaries of the date of grant. Such percentages are as follows: 50 % for a non-employee chairman of the Board, 35 % for non-employee members of the Board, and 50 % - 70 % for executive officers.

 The following table summarizes our compensation costs recognized in General and administrative expense (excluding depreciation) and Operating expense (excluding depreciation) under the Amended and Restated Incentive Plan and Stock Purchase Plan (in thousands):

 Years Ended December 31,

 2023
 2022
 2021

 Restricted Stock Awards
 $
 7,774
 $
 5,172
 $
 4,657

 Restricted Stock Units
 1,931
 1,451
 1,356

 Stock Option Awards
 1,637
 2,540
 1,939

 Employee Stock Purchase Plan
 Under the Par Pacific Holdings, Inc. 2018 Employee Stock Purchase Plan ("ESPP"), eligible employees may elect to purchase the Company's common stock at 85 % of the market price on the purchase date. Eligible employees may invest from 0 % to 10 % of their annual income subject to a $ 15 thousand annual maximum. The Board, or a committee of the Board, is authorized to set the market price discount percentages, any holding periods, and other purchasing terms and timing. The Company's shareholders ratified the ESPP on May 8, 2018. The maximum number of shares that may be issued under the ESPP is 800 thousand shares of common stock. At December 31, 2023, 374 thousand shares remained available under the ESPP.
 During each of the years ended December 31, 2023, 2022, and 2021, we recognized $ 0.3 million of compensation costs in General and administrative expense (excluding depreciation) and Operating expense (excluding depreciation) related to the 15 % discount offered to employees under the ESPP. During the years ended December 31, 2023, 2022, and 2021, employees purchased 61 thousand, 67 thousand, and 85 thousand shares under the ESPP, respectively.
 Management Stock Purchase Plan
 On February 26, 2019, our Board approved the Par Pacific Holdings, Inc. 2019 Management Stock Purchase Plan (the "MSPP"). The MSPP provides executive management with an opportunity to receive restricted stock units ("RSUs") by converting a portion of their cash bonus compensation into RSUs ("Deferred RSUs") and receiving awards of matching RSUs, the amount of which are determined by the amount of compensation converted ("Matching RSUs"). A Deferred RSU and a Matching RSU each represents a right to receive one share of the Company's common stock in the future, subject to the terms and conditions of the MSPP, including, but not limited to, vesting requirements. Shares of common stock issued pursuant to awards of Deferred RSUs and Matching RSUs will be issued from the shares reserved for issuance under the LTIP. As of December 31, 2023, no Deferred RSUs or Matching RSUs had been issued under the MSPP.
 Restricted Stock Awards and Restricted Stock Units
 The following tables summarize our restricted stock activity (in thousands, except per share amounts):

 Shares
 Weighted-
Average
Grant Date Fair
Value

 Unvested balance at December 31, 2022
 $
 16.24

 Granted
 26.30

 Vested
 ( 375)
 17.81

 Forfeited
 ( 21)
 19.20

 Unvested balance at December 31, 2023
 $
 20.90

 Years Ended December 31,

 2023
 2022
 2021

 Weighted-average grant-date fair value per share of restricted stock awards and restricted stock units granted (in dollars)
 $
 26.30
 $
 15.27
 $
 16.38

 Fair value of restricted stock awards and restricted stock units vested
 $
 6,677
 $
 5,718
 $
 4,370

 As of December 31, 2023 and 2022, there were approximately $ 11.4 million and $ 8.8 million of total unrecognized compensation costs related to restricted stock awards and restricted stock units, which are expected to be recognized on a straight-line basis over a weighted-average period of 1.46 years and 1.69 years, respectively.
 Performance Restricted Stock Units
 The following tables summarize our performance restricted stock activity (in thousands, except per unit amounts):

 Units
 Weighted-
Average
Grant Date Fair
Value

 Unvested balance at December 31, 2022
 $
 16.78

 Granted
 27.47

 Vested
 ( 36)
 19.17

 Forfeited
 —
 —

 Unvested balance at December 31, 2023
 $
 22.03

 Years Ended December 31,

 2023
 2022
 2021

 Weighted-average grant-date fair value per share of performance restricted stock units granted (in dollars)
 $
 27.47
 $
 14.91
 $
 16.52

 Fair value of performance restricted stock units vested
 $
 $
 1,343
 $

 Performance restricted stock units are subject to certain annual performance targets based on three-year performance periods as defined by our Board. As of December 31, 2023 and 2022, there were approximately $ 2.0 million and $ 0.7 million of total unrecognized compensation costs related to the performance restricted stock units, which are expected to be recognized on a straight-line basis over a weighted-average period of 1.99 years and 1.69 years, respectively.
 Stock Option Grants
 The fair value of each option is estimated on the grant date using the Black-Scholes option pricing model. The expected term represents the period of time that options are expected to be outstanding and is based upon the term of the option. The expected volatility represents the extent to which our stock price is expected to fluctuate between the grant date and the expected term of the award. We do not use an expected dividend yield in our fair value measurement as we are restricted from the payment of dividends. The risk-free rate is the implied yield available on U.S. Treasury securities with a remaining term equal to the expected term of the option at the date of grant. The weighted-average assumptions used to measure stock options granted during 2022 and 2021 are presented below. There were no stock options granted in 2023.

 2022
 2021

 Expected life from date of grant (in years)
 5.3
 5.3

 Expected volatility
 55.4 %
 53.2 %

 Risk-free interest rate
 1.83 %
 0.64 %

 The following table summarizes our stock option activity (in thousands, except per share amounts and term years):

 Number of Options
 Weighted-Average
Exercise
Price
 Weighted-Average
Remaining
Contractual
Term in Years
 Aggregate
Intrinsic
Value

 Outstanding balance at December 31, 2022
 2,020
 $
 17.92
 4.3
 $
 10,779

 Issued
 —
 —

 Exercised
 ( 705)
 19.68

 Forfeited / canceled / expired
 —
 —

 Outstanding balance at December 31, 2023
 1,315
 $
 16.97
 4.1
 $
 25,509

 Exercisable, end of year
 $
 17.60
 3.2
 $
 16,390

 The estimated weighted-average grant-date fair value per share of options granted during the year ended December 31, 2022 and 2021, was $ 7.44, and $ 7.72, respectively. No options were granted during the year ended December 31, 2023.
 As of December 31, 2023 and 2022, there were approximately $ 2.1 million and $ 3.7 million of total unrecognized compensation costs related to stock option awards, which are expected to be recognized on a straight-line basis over a weighted-average period of 1.40 years and 1.79 years, respectively.

 Note 20— Benefit Plans
 Defined Contribution Plans
 We maintain defined contribution plans for our employees. All eligible employees may participate in our Par plan after thirty days of service. For all employees participating in the Par plan, excluding participating U.S. Oil union employees, we match employee contributions up to a maximum of 6 % of the employee's eligible compensation, with the employer contributions vesting at 100 %. Beginning in January 2021 and as part of cost reductions in response to the impact of the COVID-19 pandemic on our businesses, we temporarily suspended matching employee contributions for salaried employees with 2020 annual earnings in excess of the IRS highly compensated limit of $ 130,000. In January 2022, we resumed matching of all previously-suspended employee contributions. For the years ended December 31, 2023, 2022, and 2021, we made contributions to the plans totaling approximately $ 7.5 million, $ 5.2 million, and $ 3.1 million, respectively.
 Defined Benefit Plans
 We maintain defined benefit pension plans (the "Benefit Plans") covering eligible Wyoming Refining employees and the employees of U.S. Oil covered by a collective bargaining agreement. Benefits under our Wyoming Refining plan are based on years of service and the employee's highest average compensation received during five consecutive years of the last ten years of employment. Benefits under our U.S. Oil plan are based on the employee's hourly rate of compensation at the beginning of each year of employment. Our funding policy is to contribute annually an amount equal to the pension expense, subject to the minimum funding requirements of the Employee Retirement Income Security Act of 1974 and the tax deductibility of such contributions. In December 2016, the Wyoming Refining plan was amended to freeze all future benefit accruals for salaried employees.
 In March 2021, the Wyoming Refining plan was amended (the "Plan Amendment") to freeze all future benefit accruals for hourly plan participants. The Plan Amendment reduced the projected benefit obligation by $ 6.0 million. We recorded a $ 2.0 million Gain on curtailment of pension obligation in our consolidated statements of operations for the year ended December 31, 2021, and an unrealized actuarial gain of $ 4.0 million as Other post-retirement benefits income (loss), net of tax, in our consolidated statements of other comprehensive income for the year ended December 31, 2021. Similar to the evaluation done for the estimate as of December 31, 2020, the projected benefit obligation estimate was determined based on the present value of projected future benefit payments. In determining the discount rate, we used pricing and yield information for high-quality corporate bonds that result in payments similar to the estimated distributions of benefits from our plans. The weighted average discount rate used to determine benefit obligations increased from 2.65 % to 3.25 %, or 23 %, from December 31, 2020 to March 31, 2021. The estimated rate of compensation increase remained 3 % at the time of curtailment.

 The changes in the projected benefit obligation and the fair value of plan assets of our Benefit Plans for the years ended December 31, 2023 and 2022 were as follows (in thousands):

 2023
 2022

 Changes in projected benefit obligation:

 Projected benefit obligation as of the beginning of the period
 $
 41,367
 $
 56,411

 Service cost

 Interest cost

 2,044
 1,538

 Plan amendment

 —
 —

 Actuarial loss (gain) (1)
 1,362
 ( 15,178)

 Benefits paid

 ( 1,980)
 ( 2,225)

 Curtailment
 —
 —

 Projected benefit obligation as of the end of the period
 $
 43,287
 $
 41,367

 Changes in fair value of plan assets:

 Fair value of plan assets as of the beginning of the period
 $
 40,639
 $
 49,821

 Actual return (loss) on plan assets

 3,800
 ( 6,957)

 Employer contributions

 —
 —

 Benefits paid

 ( 1,980)
 ( 2,225)

 Fair value of plan assets as of the end of the period
 $
 42,459
 $
 40,639

 ____________________________________________________
 (1)For the year ended December 31, 2023, the change in the actuarial loss was due to a decrease in the discount rate. For the year ended December 31, 2022, the change in the actuarial gain was due to an increase in the discount rate.
 The underfunded status of our Benefit Plans is recorded within Other liabilities on our consolidated balance sheets and the funded status of our Benefit Plans is recorded within Other long-term assets on our consolidated balance sheets. The reconciliation of the funding status of our Benefit Plans of December 31, 2023 and 2022 was as follows:

 2023
 2022

 WY Refining
 U.S. Oil
 WY Refining
 U.S. Oil

 Projected benefit obligation
 $
 25,582
 $
 17,705
 $
 24,730
 $
 16,637

 Fair value of plan assets
 22,219
 20,240
 21,940
 18,699

 Underfunded/(overfunded) status
 $
 3,363
 $
 ( 2,535)
 $
 2,790
 $
 ( 2,062)

 Amounts recognized in consolidated balance sheet:

 Non-current assets
 $
 —
 $
 2,535
 $
 —
 $
 2,062

 Non-current liabilities
 ( 3,363)
 —
 ( 2,790)
 —

 Net amount recorded
 $
 ( 3,363)
 $
 2,535
 $
 ( 2,790)
 $
 2,062

 Gross amounts recognized in accumulated other comprehensive income (loss): (1)

 Net actuarial gain (loss)
 $
 4,546
 $
 $
 5,243
 $
 ( 318)

 Total accumulated other comprehensive income (loss)
 $
 4,546
 $
 $
 5,243
 $
 ( 318)

 ____________________________________________________
 (1) For the years ended December 31, 2023 and 2022, we recognized an immaterial amount of service costs (credits) in accumulated other comprehensive income.

 Weighted-average assumptions used to measure our projected benefit obligation as of December 31, 2023, 2022, and 2021 and net periodic benefit costs for the years ended December 31, 2023, 2022 and 2021 are as follows:

 2023
 2022
 2021

 Projected benefit obligation:

 Wyoming Refining plan

 Discount rate (1)
 4.95
 %
 5.15
 %
 2.85
 %

 Rate of compensation increase
 —
 %
 —
 %
 —
 %

 U.S. Oil plan

 Discount rate (1)
 4.80
 %
 5.00
 %
 2.70
 %

 Rate of compensation increase
 3.00
 %
 3.00
 %
 3.00
 %

 Net periodic benefit costs:

 Wyoming Refining plan

 Discount rate (1)
 5.15
 %
 2.85
 %
 3.25
 %

 Expected long-term rate of return (2)
 6.20
 %
 5.75
 %
 5.75
 %

 Rate of compensation increase
 —
 %
 —
 %
 3.00
 %

 U.S. Oil plan

 Discount rate (1)
 5.00
 %
 2.70
 %
 2.35
 %

 Expected long-term rate of return (2)
 6.00
 %
 6.00
 %
 6.00
 %

 Rate of compensation increase
 3.00
 %
 3.00
 %
 3.00
 %

 (1)In determining the discount rate, we use pricing and yield information for high-quality corporate bonds that result in payments similar to the estimated distributions of benefits from our plans.
 (2)The expected long-term rate of return is based on the target asset allocation of each plan and capital market assumptions developed using forward-looking models and historical market data and trends.
 The net periodic benefit cost (credit) for the years ended December 31, 2023, 2022, and 2021 includes the following components:

 2023
 2022
 2021

 Components of net periodic benefit cost (credit):

 Service cost
 $
 $
 $
 1,140

 Interest cost
 2,044
 1,538
 1,538

 Expected return on plan assets
 ( 2,151)
 ( 2,596)
 ( 2,375)

 Amortization of net loss
 ( 244)

 Amortization of prior service cost
 ( 45)
 —
 —

 Effect of curtailment
 —
 —
 ( 2,032)

 Net periodic benefit cost (credit)
 $
 $
 ( 234)
 $
 ( 1,484)

 The Service cost component of net periodic benefit cost is included in Operating expense (excluding depreciation) on our consolidated statement of operations for the years ended December 31, 2023, 2022, and 2021. The other components of net periodic benefit cost are included in Other income (expense), net on our consolidated statement of operations for the years ended December 31, 2023, 2022, and 2021.

 The weighted-average asset allocation for our Wyoming Refining plan at December 31, 2023 is as follows:

 Target
 Actual

 Asset category:

 Equity securities
 %
 %

 Debt securities
 %
 %

 Real estate
 %
 %

 Total
 %
 %

 The weighted-average asset allocation for our U.S. Oil plan at December 31, 2023 is as follows:

 Target
 Actual

 Asset category:

 Equity securities
 %
 %

 Debt securities
 %
 %

 Cash and Cash Equivalents
 %
 —
 %

 Total
 %
 %

 We have a long-term, risk-controlled investment approach using diversified investment options with minimal exposure to volatile investment options like derivatives. Our Benefit Plans' assets are invested in pooled separate accounts administered by the Benefit Plans' custodians. The underlying assets in the pooled separate accounts are invested in equity securities, debt securities, real estate, or cash and cash equivalents. The pooled separate accounts are valued based upon the fair market value of the underlying investments and are deemed to be Level 2.
 We intend to make contributions in the amount of approximately $ 0.5 million to the Wyoming Refining plan and do not intend to make any contributions to the U.S. Oil plan during 2024. Based on current data and assumptions, the following benefit payments, which reflect expected future service, as appropriate, are expected to be paid over the next 10 years:

 Year Ended

 2024
 $
 2,393

 2025
 2,436

 2026
 2,664

 2027
 2,669

 2028
 2,737

 Thereafter
 13,698

 $
 26,597

 Note 21— Income (Loss) Per Share
 The following table sets forth the computation of basic and diluted income (loss) per share (in thousands, except per share amounts):

 2023
 2022
 2021

 $
 $
 $

 Plus: Net income effect of convertible securities
 —
 —
 —

 Numerator for diluted income (loss) per common share
 $
 $
 $

 Basic weighted-average common stock shares outstanding
 60,035
 59,544
 58,268

 Plus: dilutive effects of common stock equivalents (1)
 —

 Diluted weighted-average common stock shares outstanding
 61,014
 59,883
 58,268

 Basic income (loss) per common share
 $
 12.14
 $
 6.12
 $
 ( 1.40)

 Diluted income (loss) per common share
 $
 11.94
 $
 6.08
 $
 ( 1.40)

 Diluted income (loss) per common share excludes the following equity instruments because their effect would be anti-dilutive:

 Shares of unvested restricted stock

 Shares of stock options
 1,868
 2,386

 Common stock equivalents using the if-converted method of settling the 5.00 % Convertible Senior Notes (2)

 —
 —
 1,230

 (1)Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. We have utilized the basic shares outstanding to calculate both basic and diluted loss per common share for the year ended December 31, 2021.
 (2)We had no 5.00 % Convertible Senior Notes outstanding for the years ended December 31, 2023 and 2022.

 Note 22— Income Taxes
 For the year ended December 31, 2023, we recorded an income tax benefit of $ 115.3 million primarily driven by a non-cash deferred tax benefit of $ 277.7 million related to the release of a majority of the valuation allowance against our federal net deferred tax assets, partially offset by deferred tax expense from net operating loss utilization and state tax expense. For the year ended December 31, 2022, we recorded an income tax expense of $ 0.7 million primarily driven by an increase in state taxable income. For the year ended December 31, 2021, we recorded an income tax expense of $ 1.0 million primarily driven by foreign withholding taxes.
 In connection with our emergence from bankruptcy on August 31, 2012, we experienced an ownership change as defined under Section 382 of the Code. Section 382 generally places a limit on the amount of NOL carryforwards and other tax attributes arising before an ownership change that may be used to offset taxable income after an ownership change. We believe that we have qualified for an exception to the general limitation rules under Code Section 382(l)(5) which provides for substantially less restrictive limitations on our NOL carryforwards. Our amended and restated certificate of incorporation places restrictions upon the ability of certain equity interest holders to transfer their ownership interest in us. These restrictions are designed to provide us with the maximum assurance that another ownership change does not occur that could adversely impact our NOL carryforwards.
 Our net taxable income must be apportioned to various states based upon the income tax laws of the states in which we derive our revenue. Our NOL carryforwards will not always be available to offset taxable income apportioned to the various states. The states from which our refining, logistics, and retail revenues are derived are not the same states in which our NOLs were incurred; therefore, we expect to incur state tax liabilities in connection with our refining, logistics, and retail operations.
 In the fourth quarter of 2023, we analyzed projections for our future taxable income and the absence of objective negative evidence, such as a cumulative loss in recent years. As a result of this analysis we determined that we have sufficient

 positive evidence to release a majority of the valuation allowance against our federal net deferred tax assets and recognized a non-cash deferred tax benefit of $ 277.7 million for the year ended December 31, 2023. We retain a partial valuation allowance on a foreign tax credit and certain state deferred tax assets primarily as a result of apportionment factors from minimal activity in certain states impacting assessed likelihood of future realizability. We will continue to reassess whether the balance of the valuation allowance is appropriate on a quarterly basis and, given the totality of the facts and circumstances, both positive and negative, will adjust the remaining valuation allowance in future periods if the evidence supports doing so.
 Income tax expense (benefit) consisted of the following (in thousands):

 2023
 2022
 2021

 Current:

 U.S.—Federal
 $
 —
 $
 —
 $
 —

 U.S.—State
 10,883

 Foreign
 —
 1,255

 Deferred:

 U.S.—Federal
 ( 133,979)
 ( 223)

 U.S.—State
 7,760
 ( 37)

 Total
 $
 ( 115,336)
 $
 $
 1,021

 Income tax expense was different from the amounts computed by applying U.S. Federal income tax rate to pretax income as a result of the following:

 2023
 2022
 2021

 Federal statutory rate
 21.0
 %
 21.0
 %
 21.0
 %

 State income taxes, net of federal benefit
 2.9
 %
 0.1
 %
 —
 %

 Foreign taxes
 —
 %
 —
 %
 ( 1.6)
 %

 Change in valuation allowance related to current activity
 ( 45.3)
 %
 ( 21.3)
 %
 ( 20.1)
 %

 Permanent items
 0.4
 %
 0.4
 %
 ( 0.6)
 %

 Other

 2.2
 %
 —
 %
 —
 %

 Actual income tax rate
 ( 18.8)
 %
 0.2
 %
 ( 1.3)
 %

 Deferred tax assets (liabilities) are comprised of the following (in thousands):

 2023
 2022

 Deferred tax assets:

 Net operating loss
 $
 244,243
 $
 308,457

 Intangible assets
 —

 Environmental credit obligations
 11,280
 71,424

 ROU Liabilities

 87,686
 89,879

 Other
 13,313
 5,332

 Total deferred tax assets
 356,522
 475,922

 Valuation allowance
 ( 52,755)
 ( 330,456)

 Net deferred tax assets
 303,767
 145,466

 Deferred tax liabilities:

 Inventory
 2,681
 5,891

 Property and equipment
 90,882
 54,124

 Intangible assets
 —

 ROU Assets

 89,087
 91,112

 Total deferred tax liabilities
 183,161
 151,127

 Total deferred tax assets (liabilities), net (1)

 $
 120,606
 $
 ( 5,661)

 ______________________________________________________
 (1)As of December 31, 2023, deferred tax assets (liabilities), net, is included in Other long-term assets on our consolidated balance sheets. As of December 31, 2022, deferred tax assets (liabilities), net, is included in Other liabilities on our consolidated balance sheets.
 We have NOL carryforwards as of December 31, 2023 of $ 0.9 billion for federal income tax purposes. If not utilized, approximately $ 0.7 billion of our NOL carryforwards will expire during 2030 through 2037. Approximately $ 0.2 billion of our NOL carryforwards do not expire. We do not have any unrecognized tax benefits as of December 31, 2023.

 Note 23— Segment Information
 We report the results for the following four reportable segments: (i) Refining, (ii) Logistics, (iii) Retail, and (iv) Corporate and Other.
 Summarized financial information concerning reportable segments consists of the following (in thousands):

 For the year ended December 31, 2023
 Corporate, Eliminations, and Other (1)
 Total

 $
 7,969,480
 $
 260,779
 $
 592,480
 $
 ( 590,784)
 $

 6,845,834
 145,944
 437,198
 ( 590,867)

 373,612
 24,450
 87,525
 —

 81,017
 25,122
 11,462
 2,229

 —
 —
 —
 —
 —

 —
 —
 —

 ( 7,363)
 ( 4,481)
 —
 —
 ( 11,844)

 —
 —
 —

 —
 —
 —

 —
 ( 308)
 ( 59)

 $
 676,161
 $
 69,744
 $
 56,603
 $
 ( 122,502)
 $

 ( 72,450)

 ( 19,182)

 Other expense, net
 ( 53)

 Income before income taxes
 613,306

 Income tax benefit
 115,336

 $

 $
 2,904,563
 $
 530,214
 $
 256,711
 $
 172,462
 $

 39,821
 55,232
 34,222
 —
 129,275

 42,711
 18,916
 18,801
 1,849
 82,277

 (1)Includes eliminations of intersegment revenues and cost of revenues of $ 590.8 million for the year ended December 31, 2023.

 For the year ended December 31, 2022
 Corporate, Eliminations, and Other (1)
 Total

 $
 7,046,060
 $
 198,821
 $
 570,206
 $
 ( 493,302)
 $

 6,332,694
 109,458
 428,712
 ( 494,850)

 236,989
 14,988
 81,229
 —

 65,472
 20,579
 10,971
 2,747

 —
 —
 —
 —
 —

 —
 —
 —

 —
 —
 —
 3,663
 3,663

 9,003
 —
 —
 —
 9,003

 ( 253)
 ( 169)

 $
 401,901
 $
 54,049
 $
 49,238
 $
 ( 67,285)
 $

 ( 68,288)

 ( 5,329)

 —

 Other income, net

 Income before income taxes
 364,899

 Income tax expense
 ( 710)

 $

 $
 2,580,298
 $
 412,336
 $
 244,233
 $
 43,780
 $

 39,821
 55,232
 34,272
 —
 129,325

 31,967
 12,094
 7,652
 1,312
 53,025

 (1)Includes eliminations of intersegment revenues and cost of revenues of $ 493.3 million for the year ended December 31, 2022.

 For the year ended December 31, 2021
 Corporate, Eliminations, and Other (1)
 Total

 $
 4,471,111
 $
 184,734
 $
 456,416
 $
 ( 402,172)
 $

 4,306,371
 96,828
 337,476
 ( 402,201)

 203,511
 14,722
 71,845
 —

 58,258
 22,044
 10,880
 3,059

 1,838
 —
 —
 —
 1,838

 —
 —
 —

 —
 —
 —

 9,591
 —
 —
 —
 9,591

 ( 19,659)
 ( 19)
 ( 45,034)
 ( 64,697)

 $
 ( 88,799)
 $
 51,159
 $
 81,249
 $
 ( 51,228)
 $
 ( 7,619)

 ( 66,493)

 ( 8,144)

 2,032

 Other expense, net
 ( 52)

 Loss before income taxes
 ( 80,276)

 Income tax expense
 ( 1,021)

 Net loss
 $

 $
 1,928,987
 $
 398,182
 $
 228,245
 $
 14,837
 $
 2,570,251

 39,821
 55,232
 32,209
 —
 127,262

 15,689
 6,801
 5,917
 1,126
 29,533

 (1)Includes eliminations of intersegment revenues and cost of revenues of $ 402.2 million for the year ended December 31, 2021.

 SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT
 PAR PACIFIC HOLDINGS, INC. (PARENT ONLY)
 BALANCE SHEETS
 (in thousands, except share data)

 ASSETS

 Current assets

 Cash and cash equivalents
 $
 10,369
 $
 2,547

 Restricted cash

 Total cash, cash equivalents, and restricted cash
 10,708
 2,878

 4,767
 2,229

 Due from subsidiaries
 380,159
 229,431

 Total current assets
 395,634
 234,538

 21,350
 19,865

 ( 16,487)
 ( 14,967)

 4,863
 4,898

 Long-term assets

 Operating lease right-of-use ("ROU") assets
 7,005
 2,649

 Investment in subsidiaries
 1,070,518
 487,943

 $
 1,478,746
 $
 730,751

 LIABILITIES AND STOCKHOLDERS' EQUITY

 Current liabilities

 Accounts payable
 $
 4,991
 $
 4,176

 Accrued taxes
 —

 —

 Due to subsidiaries
 128,922
 77,420

 Total current liabilities
 134,860
 82,941

 Long-term liabilities

 8,462
 3,273

 143,322
 86,214

 Stockholders' equity

 Preferred stock, $ 0.01 par value: 3,000,000 shares authorized, none issued

 —
 —

 Common stock, $ 0.01 par value; 500,000,000 shares authorized at December 31, 2023 and December 31, 2022, 59,755,844 shares and 60,470,837 shares issued at December 31, 2023 and December 31, 2022, respectively

 Additional paid-in capital

 Accumulated earnings (deficit)
 ( 200,687)

 Accumulated other comprehensive income (loss)
 8,174
 8,129

 Total stockholders' equity

 Total liabilities and stockholders' equity
 $
 1,478,746
 $
 730,751

 This statement should be read in conjunction with the notes to consolidated financial statements.

 SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT
 PAR PACIFIC HOLDINGS, INC. (PARENT ONLY)
 STATEMENTS OF OPERATIONS

 2023
 2022
 2021

 $
 1,618
 $
 2,131
 $
 2,452

 29,258
 17,882
 12,435

 —
 3,396

 30,906
 23,436
 14,989

 Operating loss
 ( 30,906)
 ( 23,436)
 ( 14,989)

 ( 24)
 ( 1)
 ( 2,600)

 ( 20)
 ( 33)

 Equity in earnings (losses) from subsidiaries
 759,528
 388,008
 ( 63,649)

 Total other income (expense), net
 759,548
 387,987
 ( 66,282)

 364,551
 ( 81,271)

 Income tax benefit (expense)
 —
 ( 362)
 ( 26)

 $
 $
 $

 This statement should be read in conjunction with the notes to consolidated financial statements.

 SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT
 PAR PACIFIC HOLDINGS, INC. (PARENT ONLY)
 STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

 2023
 2022
 2021

 $
 $
 $

 Other comprehensive income: (1)

 Other post-retirement benefits income, net of tax
 5,627
 6,244

 Total other comprehensive income, net of tax
 5,627
 6,244

 Comprehensive income (loss)
 $
 728,687
 $
 369,816
 $
 ( 75,053)

 ____________________________________________________
 (1) Other comprehensive income relates to benefit plans at our subsidiaries.

 This statement should be read in conjunction with the notes to consolidated financial statements.

 SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT
 PAR PACIFIC HOLDINGS, INC. (PARENT ONLY)
 STATEMENTS OF CASH FLOWS

 2023
 2022
 2021

 Cash flows from operating activities:

 $
 $
 $

 Adjustments to reconcile net income (loss) to cash used in operating activities:

 1,618
 2,131
 2,452

 Non-cash interest expense
 —
 —
 1,364

 11,633
 9,353
 8,165

 Equity in losses (income) of subsidiaries
 ( 759,528)
 ( 388,008)
 63,649

 Net changes in operating assets and liabilities:

 Prepaid and other assets
 ( 2,541)
 13,436
 1,318

 Accounts payable, other accrued liabilities, and operating lease ROU assets and liabilities
 1,113
 2,651
 ( 1,380)

 Net cash provided by (used in) operating activities
 ( 19,033)
 3,779
 ( 5,714)

 Cash flows from investing activities:

 Investments in subsidiaries
 ( 76,000)
 —
 ( 146,056)

 Distributions from subsidiaries
 167,181
 —
 90,183

 ( 1,849)
 ( 1,311)
 ( 1,126)

 Due to (from) subsidiaries
 ( 13,408)
 5,645
 29,752

 Net cash provided by (used in) investing activities
 75,924
 4,334
 ( 27,247)

 Cash flows from financing activities:

 Proceeds from sale of common stock, net of offering costs
 —
 —
 87,193

 Proceeds from borrowings
 —
 —
 12,364

 Repayments of borrowings
 —
 ( 9,319)
 ( 62,111)

 ( 67,821)
 ( 7,834)
 ( 2,145)

 17,129
 6,444

 Other financing activities, net
 1,631
 1,058
 1,208

 Net cash provided by (used in) financing activities
 ( 49,061)
 ( 9,651)
 36,567

 Net increase (decrease) in cash, cash equivalents, and restricted cash
 7,830
 ( 1,538)
 3,606

 Cash, cash equivalents, and restricted cash at beginning of period
 2,878
 4,416

 Cash, cash equivalents, and restricted cash at end of period
 $
 10,708
 $
 2,878
 $
 4,416

 Supplemental cash flow information:

 Net cash received (paid) for:

 Interest
 $
 —
 $
 ( 3)
 $
 ( 1,230)

 Taxes
 ( 5,902)
 ( 15)

 Non-cash investing and financing activities:

 Accrued capital expenditures
 $
 $
 $

 ROU assets obtained in exchange for new finance lease liabilities
 —
 —
 —

 ROU assets obtained in exchange for new operating lease liabilities
 8,161
 —

 This statement should be read in conjunction with the notes to consolidated financial statements.

 Item 16. FORM 10-K SUMMARY
 None.

 SIGNATURES
 Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange of Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized on February 29, 2024.

 PAR PACIFIC HOLDINGS, INC.

 By:
 /s/ William Pate

 William Pate

 Chief Executive Officer

 By:
 /s/ Shawn Flores

 Shawn Flores

 Senior Vice President and Chief Financial Officer

 Pursuant to the requirements of the Securities Exchange Act of 1934, this Form 10-K has been signed below by the following persons on our behalf and in the capacities indicated and on February 29, 2024.

 Signature
 Title

 /s/ WILLIAM PATE
 Chief Executive Officer and Director
(Principal Executive Officer)

 William Pate

 /s/ WILLIAM MONTELEONE
 President and Director

 William Monteleone

 /s/ SHAWN FLORES
 Senior Vice President and Chief Financial Officer
(Principal Financial Officer)

 Shawn Flores

 /s/ IVAN GUERRA
 Chief Accounting Officer
(Principal Accounting Officer)

 Ivan Guerra

 /s/ MELVYN N. KLEIN
 Chairman Emeritus

 Melvyn N. Klein

 /s/ ROBERT S. SILBERMAN
 Chairman of the Board of Directors

 Robert S. Silberman

 /s/ TIMOTHY CLOSSEY

 Timothy Clossey

 /s/ CURTIS ANASTASIO

 Curtis Anastasio

 /s/ WALTER A. DODS, JR.

 Walter A. Dods, Jr.

 /s/ KATHERINE HATCHER

 Katherine Hatcher

 /s/ ANTHONY CHASE

 Anthony Chase

 /s/ PHILIP DAVIDSON

 Philip Davidson

 /s/ PATRICIA MARTINEZ

 Patricia Martinez

 /s/ AARON ZELL

 Aaron Zell