Investor Presentation
February 2026
Company Overview
Constant focus on the safe, reliable operations of our facilities
Evaluate commercial optimization opportunities to improve margin capture in the Petroleum Segment
Actively pursue opportunities to expand our asset footprint
Maintain a disciplined approach to capital allocation
CVR Energy owns the general partner and 37% of the common units of CVR Partners, LP.
Two strategically located nitrogen fertilizer facilities serving the Southern Plains and Corn Belt.
Primarily engaged in the production of nitrogen fertilizers - ammonia and urea ammonium nitrate (UAN).
Diverse feedstock exposure through petroleum coke ("pet coke") and natural gas.
Nitrogen Fertilizer
Two strategically located Mid-Continent refineries close to Cushing, Oklahoma.
Total nameplate crude oil capacity of 206,500; average complexity rating of 10.8.
Complementary logistics assets and access to key pipelines provide a variety of advantaged crude oil supply options: 100% exposure to Brent - WTI crude differential.
Historically high product yield vs. peers: 97% liquid volume yield and 90% yield of gasoline and distillate.(1)
Petroleum Refining
(1) Based on total throughputs; for the twelve months ended December 31, 2025. 2
Petroleum Segment Overview
Crude Throughput
Competitively Positioned Mid-Con Refineries
Nameplate crude oil capacity of 206,500 bpd across two refineries with an average complexity rating of 10.8.
Located in Group 3 of PADD II.
Significant crude oil sourcing optionality via proprietary pipeline and truck gathering systems, close proximity to major crude oil hub at Cushing, and contracted space on Keystone and Spearhead pipelines for Canadian crude oil deliveries.
Multiple product sales outlets between refinery racks, ONEOK and NuStar pipeline systems and racks, and the bulk product market.
Rail logistics assets at both refineries provide additional
product marketing opportunities outside of Group 3.
New refined product pipeline capacity scheduled to come online later in 2026 to provide additional outlet from Group 3 to Denver.
Product Slate(3)
Nameplate Capacity (bpd) | Avg. Utilization(1)(2) | Gasoline | Distillate | Other Liquids | Other | ||
Coffeyville | 132,000 | 75% | 49% | 44% | 4% | 3% | |
Wynnewood 74,500 92% | 54% | 35% | 11% | 0% | |||
Consolidated | 206,500 | 81% | 51% | 41% | 6% | 2% | |
Based on crude oil throughputs for the twelve months ended December 31, 2025.
Coffeyville utilization impacted by the large, planned turnaround completed in 1H 2025. 3
Based on production for the twelve months ended December 31, 2025.
Key Operating Statistics - Petroleum
Consistent History of High Refinery Utilization Rates
Five-year average utilization of 90% including turnarounds
1Q 2025 and 2Q 2025 impacted by the large turnaround at
Coffeyville
Advantaged Crude Oil and Feedstock Slate
Over 60% of crude oil throughputs sourced locally via CVR's
proprietary gathering systems
Approximately 1,300 bpd of Canadian crude oil processed at Coffeyville, remainder sold at Cushing
High Conversion Refineries Leveraged to Diesel
Historically high product yield - 97% liquid volume yield and 90% yield of gasoline and distillate(1)
225.0
180.0
135.0
90.0
45.0
0.0
Consolidated Throughputs and Crude Oil Utilization
1Q21
2Q21
3Q21
4Q21
1Q22
2Q22
3Q22
4Q22
1Q23
2Q23
3Q23
4Q23
1Q24
2Q24
3Q24
4Q24
1Q25
2Q25
3Q25
4Q25
Crude Oil Throughput (mbpd) Other Feedstocks Throughput (mbpd)Crude Oil Utilization
100%
80%
60%
40%
20%
0%
Total Throughputs(2)
~182,000 bpd
Total Production(3)
~179,500 bpd
Based on total throughputs for the twelve months ending December 31, 2025.
Based on total throughputs for the twelve months ending December 31, 2025. Other includes natural gasoline, isobutane, normal butane and gas oil.
4
Based on total production for the twelve months ended December 31, 2025. Other includes pet coke, NGLs, slurry, sulfur and gas oil, and specialty products such as propylene and solvents; excludes internally produced fuels.
Constructive Refining Macro Environment(1)
Favorable Refining Macro Environment Driven by Reduced Domestic Supply and Stable Demand Trends
U.S. operable refining capacity has declined over 800,000 bpd since 2020 as refineries converted to renewable fuels production or shuttered due to poor economics. Additional closures have been announced for 2026.
Global net refining capacity additions are slowing, which creates potential for global demand growth to exceed refining capacity growth in 2026.
U.S. Energy Information Administration ("EIA") forecasting domestic consumption of gasoline to decline 1% in 2026 while supply also declines 1%. Distillate consumption in the U.S. is forecast to increase 1% in 2026, while supply is forecast to decline 2%.
Mid-Continent ("Mid Con") Days of Supply for gasoline continues to trend in-line with the U.S. average, while distillate has declined significantly. YTD 2026 vs YTD 2025 average Days of Supply:
Gasoline: Mid Con +0 % vs. U.S. +3%
Distillate: Mid Con -24% vs. U.S. +5%
Multiple refined product pipeline systems under construction or under development could provide additional access to regions outside
of the Mid Con, if completed.
U.S. Gasoline and Distillate Days of Supply Continue to Trend in Line with '21 - '25 Average Levels
(1) Source: EIA 5
Focused on Capture Rate Improvements
Group 3 2-1-1 crack spreads improved in 2025 - FY 2025 average of $22.63/bbl vs. FY 2024 average $18.05/bbl, although
prices for Renewable Identification Numbers ("RINs") in 2025 have increased as well.
CVR adjusted margin capture averaged 46% for FY 2025, down slightly from FY 2024 average of 48%, primarily due to the large turnaround at Coffeyville in 1H 2025 and higher RINs prices.
Currently pursuing opportunities to sustainably improve margin capture at both refineries:
Optimizing crude/feedstock slates and refined product marketing to generate the highest available netbacks.
Reversion of the Renewable Diesel Unit ("RDU") at Wynnewood back to hydrocarbon processing should allow for increased crude slate flexibility, while repurposing rail assets should provide for additional product shipment optionality and feedstock security.
Diligently pursue Small Refinery Exemptions ("SREs") at Wynnewood: Margin capture would have improved by
approximately 5% on average for 2021 - 2024 accounting for SREs granted in August 2025.
Increasing jet fuel production at Coffeyville and pursuing more opportunities to rail product west when arbs are supportive.
Historical Group 3 2-1-1 and CVR Energy Margin Capture(1)
(1) Margin Capture = Adjusted Gross Margin per barrel / Group 3 2-1-1 Benchmark including RINs. 6
Capital Allocation Strategy
Prioritize Sustaining Capital Investments
Maintaining safe, reliable operations is priority #1.
Disciplined Approach to Capital Allocation
Maintain Strong Balance Sheet and Liquidity Pursue Accretive Acquisition and Investment Opportunities Return Cash to Investors When AppropriateFocusing on debt reduction in the near-term to return to targeted leverage levels while maintaining sufficient cash balances.
Actively pursue opportunities to profitably grow our asset footprint and improve margin capture.
Dividends and distributions are quarterly determination by the Boards - debt repayment progress, cash balances and free cash flow generation are among the key criteria evaluated.
7
Capital Expenditures and Turnarounds
Petroleum Segment estimated 2026 Capex of $130MM - $145MM
Maintenance capex estimated at $80MM to $90MM.
Growth capex estimated at $50MM to $55MM.
Wynnewood Alky Project accounts for a significant
portion of the expected 2026 growth capex spend.
Currently evaluating additional low-cost/high-return opportunities aimed at increasing margin capture.
2026 Turnaround Spending of $15MM - $20MM
No planned turnarounds in the Petroleum Segment in 2026.
2026 turnaround spending associated with pre-spending for planned turnarounds currently scheduled at Wynnewood in 2027 and Coffeyville in 2028.
Currently exploring opportunities to optimize the future turnaround schedule at Coffeyville to better balance spending and increase overall throughput volumes over the turnaround cycle.
8
Nitrogen Fertilizer Segment Overview
Strategically Located Nitrogen Fertilizer FacilitiesLarge geographic footprint serving the Southern Plains and Corn Belt regions.
Well positioned to minimize distribution costs and maximize netback pricing.
Rail loading rack at the Coffeyville facility provides significant logistics optionality west of the Mississippi River due to access to both UP and BNSF delivery points.
Production sustainability due to storage capabilities at the plants and offsite locations.
Location of the Coffeyville facility allows potential for diversification of feedstock to optimize the economics between natural gas and pet coke.
Metric | Coffeyville Facility | East Dubuque Facility |
Current Ammonia / UAN Capacity | 1,300 / 3,100 Tons per day | 1,075 / 950 Tons per day |
TTM Ammonia / UAN Production Volumes(1) | 2,085 / 3,216 Tons per day (Consolidated) | |
Feedstock | Pet Coke | Natural Gas |
Distribution Methods | Rail(2)& Truck | Rail(3), Truck & Barge |
Based on production for the twelve months ended December 31, 2025.
Coffeyville Facility carries out railcar distribution via the Union Pacific ("UP") or Burlington Northern Santa Fe ("BNSF") railroad lines.
East Dubuque Facility carries out railcar distribution via the Canadian National Railway Company. 9
Key Operating Statistics - Nitrogen Fertilizer
Consistent History of High Ammonia Utilization Rates
Five-year average utilization of 93% including turnarounds.
Turnarounds typically completed every 3 years - Coffeyville turnaround completed in 4Q 2025 and East Dubuque scheduled for 3Q 2026.
Diversified Feedstock Slate
Coffeyville facility utilizes pet coke from the Coffeyville Refinery in addition to 3rd party sources, while the East Dubuque Facility uses natural gas as its primary feedstock.
Currently working on a detailed design and construction plan to allow the Coffeyville Facility to utilize natural gas and excess hydrogen from the Coffeyville Refinery as alternative feedstocks to 3rd party pet coke.
Consolidated Feedstock Costs(1)
Consolidated Product Revenue(1)(2)
For the twelve months ended December 31, 2025.
Excludes freight and other.
10
Recent Domestic Nitrogen Fertilizer Market Conditions
Strong demand for nitrogen fertilizers in the U.S. combined with domestic and global nitrogen fertilizer supply issues led to
elevated ammonia and UAN prices in 2025.
U.S. Department of Agriculture ("USDA") estimated 98.8 million acres of corn were planted in 2025, compared to
90.9 million acres in 2024.
Yield estimates of 187 bushels of corn per acre resulting in carryout inventory estimates in-line with the ten-year average.
Geopolitical issues impacted fertilizer supply throughout 2025, particularly over the summer with nitrogen fertilizer plant disruptions in Egypt, Iran and Russia all driving tightness in available supplies.
Major global nitrogen capacity build cycle was largely complete by 2018, with limited new production capacity anticipated over the next few years. U.S. projects under construction are primarily targeting export markets.
Preliminary estimates indicating 2026 corn plantings could be approximately 95 million acres. While this is a decline from 2025, inventory levels of nitrogen fertilizers remain tight across the system, which should be supportive of pricing through 1H 2026.
Domestic Corn Stocks to Use Ratios and Corn Belt Nitrogen Fertilizer Pricing Trends(1)
(1) Sources: USDA and Green Markets 11
Strong Demand for Corn in the U.S.
Corn has a variety of uses and applications, including feed grains, ethanol for fuel, and feed, seed and industrial (FSI).
Feed Grains: Approximately 96% of domestic feed grains are supplied by corn. Feed grains consume approximately 39% of the annual corn crop in the United States.(1)(2)
Ethanol: Consumes approximately 36% of the annual corn crop in the United States.(1)(2)
Corn production volumes are typically driven more by yield than acres planted.
Nitrogen fertilizer is crucial for corn yield and is generally low on the cost curve for farmers.
U.S. Domestic Corn Use(1)
Historical Corn Pricing
$4.26
Source: USDA Economic Research Service and USDA WASDE.
Based on 2020 - 2024 average. 12
Capital Expenditures and Turnaround Expenses
2026 Total Capex budget of $60MM - $75MM
Maintenance capex estimated at $35MM - $45MM.
Growth capex estimated at $25MM - $30MM.
Growth capex projects planned for 2026 primarily focused on margin improvement and debottlenecking projects at both plants.
Ammonia expansion and feedstock diversification project at the Coffeyville facility, water quality upgrade projects at both facilities and diesel exhaust fluid ("DEF") production and loadout capacity expansions.
Majority of planned growth capex to be funded through reserves taken in 2023 through 2025.
2026 Turnaround expense estimated at $30MM - $35MM
Coffeyville's planned turnaround was completed in the
fourth quarter of 2025 with a total cost of approximately
$16MM.
East Dubuque's next planned turnaround is currently
scheduled for the third quarter of 2026.
13
APPENDIX
Mission and Values
Our mission is to be a top tier North American renewable fuels, petroleum refining, and nitrogen-based fertilizer company as measured by safe and reliable operations, superior financial performance and profitable growth.
Our core values are driven by our people, inform the way we do business each and every day and enhance our ability to
accomplish our mission and related strategic objectives.
Safety - We always put safety first.
The protection of our employees, contractors and communities is paramount. We have an unwavering commitment to
safety above all else. If it's not safe, then we don't do it.
Environment - We care for our environment.
Complying with all regulations and minimizing any environmental impact from our operations is essential. We understand
our obligation to the environment and that it's our duty to protect it.
Integrity - We require high business ethics.
We comply with the law and practice sound corporate governance. We only conduct business one way - the right way with integrity.
Corporate Citizenship - We are proud members of the communities where we operate.
We are good neighbors and know that it's a privilege we can't take for granted. We seek to make a positive economic and social impact through our financial donations and contributions of time, knowledge and talent of our employees to the places where we live and work.
Continuous Improvement - We foster accountability under a performance-driven culture.
We believe in both individual and team success. We foster accountability under a performance-driven culture that supports creative thinking, teamwork, diversity and personal development so that employees can realize their maximum potential. We use defined work practices for consistency, efficiency and to create value across the organization.
15
Non-GAAP Financial Measures
Adjusted EBITDA represents EBITDA adjusted for certain significant noncash items and items that management believes are not attributable to or indicative of our on-going operations or that may obscure our underlying results and trends.
Adjusted Refining Margin and Adjusted Renewables Margin represents Refining Margin and Renewables Margin adjusted for certain significant noncash items and items that management believes are not attributable to or indicative of our underlying operational results of the period or that may obscure results and trends we deem useful.
Direct Operating Expenses per Throughput Barrel represents direct operating expenses for the Company's Petroleum segment divided by total
throughput barrels for the period, which is calculated as total throughput barrels per day times the number of days in the period.
Direct Operating Expenses per Vegetable Oil Throughput Gallon represents direct operating expenses for the Company's Renewables segment divided by total vegetable oil throughput gallons for the period, which is calculated as total vegetable oil throughput gallons per day times the number of days in the period.
EBITDA represents net income (loss) before (i) interest expense, net, (ii) income tax expense (benefit) and (iii) depreciation and amortization expense.
Refining Margin represents the difference between the Company's Petroleum segment net sales and cost of materials and other.
Refining Margin and Adjusted Refining Margin per Throughput Barrel represents Refining Margin and Adjusted Refining Margin divided by the total throughput barrels for the period, which is calculated as total throughput barrels per day times the number of days in the period.
Renewables Margin represents the difference between the Company's Renewables segment net sales and cost of materials and other.
Renewables Margin and Adjusted Renewables Margin per Vegetable Oil Throughput Gallon represents Renewables Margin and Adjusted Renewables Margin divided by the total vegetable oil throughput gallons for the period, which is calculated as total vegetable oil throughput gallons per day times the number of days in the period.
Note: Due to rounding, numbers presented within this section may not add or equal to numbers or totals presented elsewhere within this document.
16
Non-GAAP Financial Measures
(In USD Millions) | |||||||||
CVR Energy, Inc. | 2021 | 2022 | 2023 | 2024 | 1Q 2025 | 2Q 2025 | 3Q 2025 | 4Q 2025 | 2025 |
Net income (loss) | $ 74 $ 644 | $ 878 | $ 45 $ | (105) $ | (90) $ | 401 | $ (116) | 90 | ||
Add: Interest expense and other financing costs, net of interest income | 117 85 | 52 | 77 | 25 | 30 | 25 | 29 | 108 | ||
Add: Income tax expense (benefit) | (8) 157 | 207 | (26) | (49) | (42) | 88 | (7) | (10) | ||
Add: Depreciation and amortization | 279 288 | 298 | 298 | 68 | 78 | 111 | 145 | 403 | ||
EBITDA | $ 462 $ 1,174 | $ 1,435 | $ 3G4 $ | (61) $ | (24) $ | 625 | $ 51 | $ 5G1 | ||
Changes in the RFS liability | 63 | 135 | (284) | (89) | 112 | 89 | (471) | 9 | (262) | |
Gain on marketable securities and sale of equity method investment | (81) | - | - | (24) | - | - | - | - | - | |
Unrealized loss (gain) on derivatives, net | (16) | 5 | (32) | 22 | (3) | 2 | 8 | (10) | (4) | |
Inventory valuation impacts, unfavorable (favorable) | (127) | (24) | 45 | 14 | (24) | 32 | 18 | 39 | 66 | |
Call Option Lawsuits settlement | - | 79 | - | - | - | - | - | - | - | |
Other non-cash adjustments | - | - | - | - | - | - | - | 2 | 2 | |
Adjusted EBITDA | $ 301 | $ 1,36G | $ 1,164 | $ 317 | $ 24 | $ GG | $ 180 | $ G1 | $ 3G3 | |
17
Non-GAAP Financial Measures
Petroleum Segment | |||||||||
Refining Margin and Adjusted Refining Margin (: in Millions) | 2021 | 2022 | 2023 | 2024 | 1Q 2025 | 2Q 2025 | 3Q 2025 | 4Q 2025 | 2025 |
$ 6,721 $ | 9,919 $ | 8,287 $ | 6,920 $ | 1,477 $ | 1,561 $ | 1,739 $ | 1,649 $ | 6,426 |
(6,100) | (8,488) | (6,629) | (6,236) | (1,482) | (1,526) | (1,031) | (1,482) | (5,520) |
Net sales Less:
Cost of materials and other
Direct operating expenses (exclusive of depreciation and amortization) | (369) | (426) | (406) | (421) | (93) | (102) | (113) | (108) | (415) |
Depreciation and amortization | (197) | (182) | (185) | (174) | (41) | (48) | (52) | (52) | (194) |
Gross profit (loss) | 55 | 823 | 1,067 | 8G | (13G) | (115) | 543 | 7 | 2G7 |
Add: | |||||||||
Direct operating expenses (exclusive of depreciation and amortization) | 369 | 426 | 406 | 421 | 93 | 102 | 113 | 108 | 415 |
Depreciation and amortization | 197 | 182 | 185 | 174 | 41 | 48 | 52 | 52 | 194 |
Refining margin | 621 | 1,431 | 1,658 | 684 | (5) | 35 | 708 | 167 | G06 |
Adjustments: | |||||||||
Inventory valuation impacts, unfavorable (favorable) | (127) | (22) | 32 | 6 | (20) | 31 | 11 | 33 | 54 |
Unrealized loss (gain) on derivatives, net | (16) | 3 | (30) | 22 | (3) | 2 | 8 | (10) | (4) |
Changes in the RFS liability | 63 | 135 | (284) | (89) | 112 | 89 | (471) | 9 | (262) |
Adjusted refining margin | $ 541 | $ 1,547 | $ 1,376 | $ 623 | $ 84 $ | 157 | $ 256 | $ 1GG | $ 6G4 |
Petroleum Segment | |||||||||
Refining Margin and Adjusted Refining Margin per Throughput Barrel (: in Millions) | 2021 | 2022 | 2023 | 2024 | 1Q 2025 | 2Q 2025 | 3Q 2025 | 4Q 2025 | 2025 |
Refining margin | $ 621 | $ 1,431 | $ 1,658 | $ 684 | $ (5) $ | 35 | $ 708 | $ 167 | $ 906 |
Dividend by: total throughput barrels | 76 | 75 | 76 | 72 | 11 | 16 | 20 | 20 | 66 |
Refining margin per total throughput barrel | $ 8.14 | $ 1G.0G | $ 21.82 | $ G.53 | $ (0.42) $ | 2.21 | $ 35.65 | $ 8.35 | $ 13.64 |
Adjusted refining margin | $ 541 | $ 1,547 | $ 1,376 | $ 623 | $ 84 | $ 157 | $ 256 | $ 199 | $ 694 |
Dividend by: total throughput barrels | 76 | 75 | 76 | 72 | 11 | 16 | 20 | 20 | 66 |
Adjusted refining margin per throughput barrel | $ 7.12 | $ 20.65 | $ 18.11 | $ 8.67 | $ 7.72 | $ G.G5 | $ 12.87 | $ G.G2 | $ 10.45 |
Petroleum Segment | |||||||||
Direct Operating Expenses per Throughput Barrel (: in Millions) | 2021 | 2022 | 2023 | 2024 | 1Q 2025 | 2Q 2025 | 3Q 2025 | 4Q 2025 | 2025 |
Direct operating expenses | $ 369 | $ 426 | $ 406 | 421 | 93 | 102 | 113 | 108 | 415 |
Divided by: total throughput (mm bbls) | 76 | 75 | 76 | 72 | 11 | 16 | 20 | 20 | 66 |
Direct operating expenses per total throughput barrel | $ 4.83 | $ 5.68 | $ 5.34 | $ 5.86 | $ 8.58 | $ 6.45 | $ 5.6G | $ 5.40 | $ 6.25 |
18
Non-GAAP Financial Measures
Renewables Segment | ||||||||
newables Margin and Adjusted Renewables Margin (: in Millions) | 2022 | 2023 | 2024 | 1Q 2025 | 2Q 2025 | 3Q 2025 | 4Q 2025 | 2025 |
Net sales | $ 338 | $ 559 | $ 289 | $ 66 | $ 76 | $ 99 | $ 72 | $ 312 |
Less: Cost of materials and other | (342) | (537) | (245) | (50) | (71) | (99) | (69) | (288) |
Direct operating expenses (exclusive of depreciation and amortization) | (24) | (28) | (31) | (6) | (7) | (9) | (7) | (30) |
Depreciation and amortization | (16) | (20) | (25) | (6) | (6) | (36) | (68) | (115) |
Gross profit (loss) | (44) | (26) | (12) | 4 | (8) | (45) | (72) | (121) |
Add: | ||||||||
Direct operating expenses (exclusive of depreciation and amortization) | 24 | 28 | 31 | 6 | 7 | 9 | 7 | 30 |
Depreciation and amortization | 16 | 20 | 25 | 6 | 6 | 36 | 68 | 115 |
Renewables margin | (4) | 22 | 44 | 16 | 5 | - | 3 | 24 |
Adjustments: | ||||||||
Inventory valuation impacts, unfavorable (favorable) | 7 | 14 | 7 | (3) | 1 | 8 | 6 | 12 |
Unrealized loss (gain) on derivatives, net | 5 | (2) | - | - | - | - | - | - |
Other non-cash adjustments | - | - | - | - | - | - | 2 | 2 |
Adjusted renewables margin | $ 8 | $ 34 | $ 51 | $ 13 | $ 6 | $ 8 | $ 11 | $ 38 |
Renewables Segment | ||||||||
Renewables Margin and Adjusted Renewables Margin per Vegetable Oil Throughput Gallon (: in Millions) | 2022 | 2023 | 2024 | 1Q 2025 | 2Q 2025 | 3Q 2025 | 4Q 2025 | 2025 |
Renewables margin | $ (4) | $ 22 | $ 44 | $ 16 | $ 5 | $ - | $ 3 | $ 24 |
Dividend by: total vegetable oil throughput gallons | 43 | 82 | 55 | 14 | 14 | 19 | 13 | 60 |
Renewables margin per vegetable oil throughput gallon | $ (0.10) | $ 0.27 | $ 0.80 | $ 1.13 | $ 0.38 | $ (0.01) | $ 0.25 | $ 0.40 |
Adjusted Renewables margin | $ 8 | $ 34 | $ 51 | $ 13 | $ 6 | $ 8 | $ 11 | $ 38 |
Dividend by: total vegetable oil throughput gallons | 43 | 82 | 55 | 14 | 14 | 19 | 13 | 60 |
Adjusted Renewables margin per vegetable oil throughput gallon | $ 0.18 | $ 0.41 | $ 0.G3 | $ 0.G4 | $ 0.44 | $ 0.37 | $ 0.G1 | $ 0.63 |
Renewables Segment | ||||||||
rect Operating Expenses per Vegetable Oil Throughput Gallon (: in Millions) | 2022 | 2023 | 2024 | 1Q 2025 | 2Q 2025 | 3Q 2025 | 4Q 2025 | 2025 |
Direct operating expenses | $ 24 | $ 28 | $ 31 | $ 6 | $ 7 | $ 9 | $ 7 | $ 30 |
Divided by: total throughput (mm bbls) | 43 | 82 | 55 | 14 | 14 | 19 | 13 | 60 |
Direct operating expenses per vegetable oil throughput gallon | $ 0.55 | $ 0.35 | $ 0.57 | $ 0.48 | $ 0.54 | $ 0.45 | $ 0.56 | $ 0.50 |
19
| Attention: This is an excerpt of the original content. To continue reading it, access the original document here. |