393222AB0

General The following discussion and analysis provides information we believe is relevant to understand our consolidated financial condition and results of operations. This discussion should be read in conjunction with the consolidated financial statements and notes to the consolidated financial statements contained in this report together with our annual report on Form 10-K for the year ended December 31, 2025. Cautionary Information Regarding Forward-Looking Statements Forward-looking statements are made in accordance with safe harbor provisions of the Private Securities Litigation Reform Act of 1995. These statements are based on current expectations that involve a number of risks and uncertainties and do not relate strictly to historical or current facts, but rather to plans and objectives for future operations. These statements may be identified by words such as “anticipate,” “believe,” “continue,” “estimate,” “expect,” “intend,” “outlook,” “plan,” “predict,” “may,” “could,” “should,” “will” and similar expressions, as well as statements regarding future operating or financial performance or guidance, business strategy, environment, key trends and benefits of actual or planned acquisitions. Factors that could cause actual results to differ from those expressed or implied in the forward-looking statements include, but are not limited to, those discussed in Part I, Item 1A – Risk Factors of our annual report on Form 10-K for the year ended December 31, 2025 and in Part II, Item 1A, “Risk Factors” in this report, or incorporated by reference. Specifically, we may experience fluctuations in future operating results due to a number of economic conditions and other factors, including: the failure to realize the anticipated results from the new products being developed or new technologies being deployed; the failure to realize the anticipated selling, general and administrative expense savings from restructuring; local, regional and national economic conditions and the impact they may have on the company and its customers; disruption caused by health epidemics; conditions in the ethanol and biofuels industry, including a sustained decrease in the level of supply or demand for ethanol and biofuels or a sustained decrease in the price of ethanol or biofuels, distillers grains, Ultra-High Protein, and renewable corn oil; competition in the ethanol industry and other industries in which we operate; commodity market risks, including those that may result from weather conditions, changes in government policies, and global political or economic issues; the financial condition of the company’s customers and counterparties; any non-performance by customers and counterparties of their contractual obligations; changes in safety, health, environmental and other governmental policy and regulation, including changes to tax laws such as the OBBB, tariffs, renewable fuel programs, tax credit programs, and low carbon programs; risks related to acquisition and disposition activities and achieving anticipated results; risks associated with merchant trading; the results of any reviews, investigations or other proceedings by government authorities; the performance of the company; and other factors detailed in reports filed with the SEC. We believe our expectations regarding future events are based on reasonable assumptions; however, these assumptions may not be accurate or account for all risks and uncertainties. Consequently, forward-looking statements are not guaranteed. Actual results may vary materially from those expressed or implied in our forward-looking statements. In addition, we are not obligated and do not intend to update our forward-looking statements as a result of new information unless it is required by applicable securities laws. We caution investors not to place undue reliance on forward-looking statements, which represent management’s views as of the date of this report or documents incorporated by reference. Overview Incorporated in Iowa, Green Plains is a renewable fuels and agricultural technology company focused on producing low-cost, low-CI ethanol and related co-products, including high protein feeds and corn oil from locally sourced corn. Our goal is to create value through an operational excellence focus including disciplined operations, cost leadership and carbon reduction as we position the company to benefit from expanding low-carbon fuel markets. Founded in 2004, Green Plains now owns nine strategically located plants across the Midwest, capable of processing approximately 287 million bushels of corn annually, when all plants are operating. Our focus remains on operating safely, efficiently and cost-effectively while reducing the CI of our products and maintaining financial flexibility to support long term growth. Our streamlined platform is positioned to create value through our focus on operational excellence, continuous improvement and disciplined capital allocation. 35 Table of Contents We group our business activities into the following two operating segments to manage performance: •Ethanol Production. Our ethanol production segment includes the production, storage and transportation of ethanol, distillers grains, Ultra-High Protein at four plants, and renewable corn oil at nine biorefineries in Illinois, Indiana, Iowa, Minnesota and Nebraska, in addition to CCS facilities at our three Nebraska plants. At capacity, our nine facilities are capable of processing approximately 287 million bushels of corn per year and producing approximately 850 million gallons of ethanol, 2.0 million tons of distillers grains and Ultra-High Protein, and 296 million pounds of renewable corn oil, a low-carbon feedstock for biodiesel and renewable diesel. Our eight facilities currently in operation are capable of processing approximately 246 million bushels of corn and producing 730 million gallons of ethanol, 1.7 million tons of distillers grains and Ultra-High Protein, and 254 million pounds of renewable corn oil. •Agribusiness and Energy Services. Our agribusiness and energy services segment includes grain procurement, storage and commodity marketing. We market our ethanol through a third party and also sell and distribute our ethanol plant co-products, including distillers grains and corn oil. We also buy and sell natural gas and other commodities in various markets. Our carbon reduction strategy plays a central role in achieving lower CI biofuel production and participation in various clean fuel programs. Our CCS facilities are operational at our Central City, Wood River, and York facilities in Nebraska. These plants are connected to the Tallgrass Trailblazer CO2 Pipeline, while one of our Iowa and all of our Minnesota locations are committed to CCS through Summit Carbon Solutions, which projects operations commencing in 2028. CCS initiatives are expected to significantly lower CI across our platform. Based on current CI score estimates, all Green Plains facilities in operation are expected to qualify for the Section 45Z Clean Fuel Production Credit in 2026, inclusive of five non-CCS facilities. Our margins are highly dependent on commodity prices, particularly for ethanol, distillers grains, Ultra-High Protein, corn oil, soybean meal, corn, and natural gas. Since market price fluctuations of these commodities are not always correlated, our operations may be unprofitable at times. We use a range of risk management tools and hedging strategies to monitor price risk exposure at our ethanol plants and mitigate commodity volatility. Our profitability could be significantly impacted by price movements of the aforementioned commodities. Recent Developments Production Tax Credits The company has been and expects to continue to benefit from certain clean energy related tax credits as a result of recent changes in legislation. All eight of our operating ethanol plants have generated production tax credits under Section 45Z in 2026. The company has agreements to purchase RECs covering the six months ended June 30, 2026, to lower CI scores at certain plants. Based on production and CI scores for the three and six months ended June 30, 2026, the company recorded credits net of discounts totaling $68.4 million and $134.0 million, respectively, reducing costs of goods sold, related to Section 45Z production tax credits at the eight qualifying plants. Under the current statutory framework, Section 45Z production credits are set to expire in 2029. The company would then look to monetize credits available under Section 45Q until 2037. Revolver Amendment On April 17, 2026, the Revolver Facility was further amended by the Second Amendment to the Loan and Security Agreement (the “Second Revolver Amendment”). The Second Revolver Amendment, among other things, (i) extends the termination date of the Revolver Facility from March 25, 2027 to September 25, 2027 and (ii) reduces the size of the Revolver Facility commitment from $350 million to $300 million. Results of Operations During the second quarter of 2026, our plants in operation maintained an average utilization rate of approximately 88.3% of capacity, resulting in ethanol production of 160.7 mmg, compared with 193.6 mmg, or 91.3% of capacity, for the same quarter last year. The prior period utilization above has been adjusted to reflect updated capacity and for comparative purposes to align with our current period presentation. Our operating strategy is to transform our company to a value-add agricultural technology company creating lower carbon, high-value ingredients from existing resources. Depending on the margin environment, we may exercise operational discretion that results in reductions in production volumes. It is possible that throughput volumes could fluctuate in the future, depending on various factors that drive each biorefinery’s variable 36 Table of Contents contribution margin, including future driving and gasoline demand for the industry, demand for valuable co-products we produce, and the supply and pricing of renewable feedstocks needed to operate our biorefineries. U.S. Ethanol Supply and Demand According to the EIA, domestic ethanol production averaged 1.09 million barrels per day during the second quarter of 2026, which was approximately 3.0% higher than the 1.05 million barrels per day for the same quarter last year. Refiner and blender input volume was 911 thousand barrels per day for the second quarter of 2026, compared with 910 thousand barrels per day for the same quarter last year. Gasoline demand for the second quarter of 2026 was consistent with the same quarter last year at 8.9 million barrels per day during the second quarter of 2026. U.S. domestic ethanol ending stocks increased by approximately 0.6 million barrels compared to the prior year, or 2.4%, to 24.7 million barrels as of June 30, 2026. Global Ethanol Supply and Demand According to the USDA Foreign Agriculture Service, domestic ethanol exports through May 31, 2026, were approximately 1,001 mmg, up from the 890 mmg for the same period of 2025. Year to date, Canada was the largest export destination for U.S. ethanol accounting for approximately 35% of domestic ethanol export volume, driven in part by their national clean fuel standard. The Netherlands, Brazil, Colombia, South Korea and the Philippines accounted for approximately 18%, 7%, 5%, 5% and 5%, respectively, of U.S. ethanol exports. We currently estimate that net ethanol exports will range from 2.3 to 2.4 billion gallons in 2026, based on historical demand from a variety of countries and certain countries that seek to improve their air quality, reduce greenhouse gas emissions through low carbon fuel programs and eliminate MTBE from their own fuel supplies. Fluctuations in currencies relative to the U.S. Dollar could impact the U.S. ethanol competitiveness in the global market. Protein and Vegetable Oil Supply and Demand Our dried distillers grains and Ultra-High Protein ingredients compete against other ethanol producers domestically and abroad, as well as with soybean meal, canola meal, and other protein feed ingredients. Likewise our distillers corn oil, which is a feedstock for producing biodiesel, renewable diesel and to some extent SAF, competes against other vegetable oils such as soybean oil, canola oil, and to some extent palm oil, as well as against waste oils such as used cooking oils, animal fats and tallow. While global protein demand has continued to grow, so too has the production of vegetable proteins, most notably in U.S. soy crushing capacity. Soybean processing capacity in the U.S. has been expanding to meet the rising demand for vegetable oils to produce renewable fuels. According to the National Oilseed Processors Association, for the second quarter of 2026, soybean crush was approximately 635.0 million bushels, up 66.3 million bushels from the 568.7 million bushels crushed during the second quarter of 2025. Soybean oil stocks for the second quarter of 2026 were 1.5 billion pounds compared with 1.4 billion pounds for the same quarter last year. Soybean meal production was 15.1 million short tons for the second quarter of 2026, up 1.6 million short tons from the 13.5 million short tons from the same period in the prior year. Legislation and Regulation We are sensitive to domestic and foreign government programs and policies that affect the supply and demand for ethanol and other fuels, which in turn may impact the volume of ethanol and other products we handle. Over the years, various bills and amendments have been proposed in the House and Senate, which would eliminate the RFS entirely, eliminate the corn based ethanol portion of the mandate, lower the price of RINs and make it more difficult to sell fuel blends with higher levels of ethanol. Bills have also been introduced to require or otherwise incentivize higher levels of octane blending, allow for year-round sales of higher blends of ethanol, require car manufacturers to produce vehicles that can operate on higher ethanol blends and provide incentives for reducing the CI of biofuels including ethanol. In addition, the manner in which the EPA administers the RFS and related regulations can have a significant impact on the actual amount of ethanol and other biofuels blended into the domestic fuel supply. Federal and foreign mandates and state-level clean fuel standards supporting the use of renewable fuels are a significant driver of ethanol demand in the U.S. Ethanol policies are influenced by concerns for the environment, diversifying the fuel supply, supporting U.S. farmers and reducing the country’s dependence on foreign oil. Consumer acceptance of FFVs, availability of higher ethanol blends and increased use of higher ethanol blends in non-FFVs may be necessary before ethanol can achieve further growth in the U.S. light duty surface transportation fleet market share. In addition, expansion of clean fuel standards in other states and countries, or a national LCFS could increase the demand for ethanol, depending on how they are structured. Incentives for automakers to produce FFVs phased out in 2020, and the 37 Table of Contents way in which the EPA implements the Corporate Average Fuel Economy (CAFE) standards has fluctuated between further incentivizing EV production and being more accommodating to liquid fuels, depending on the administration. The Clean Fuel Production Credit under Section 45Z of the Internal Revenue Code was enacted as part of the IRA and subsequently amended by the OBBB. Section 45Z provides a production tax credit for domestically produced transportation fuel with lifecycle greenhouse gas emissions below a specified threshold for fuel produced after December 31, 2024 and sold before January 1, 2030. The value of the credit is determined based on the fuel’s CI score, subject to prevailing wage and apprenticeship requirements, and may be transferred to third parties. On February 3, 2026, the U.S. Department of the Treasury and the Internal Revenue Service issued proposed regulations governing administration of the Section 45Z Clean Fuel Production Credit. The proposed regulations provide guidance on credit eligibility, emissions rate determination, registration and certification requirements, and implementation of amendments made by the OBBB. Among other things, the proposed regulations (i) limit eligible feedstocks to those grown or produced in the United States, Canada, or Mexico; (ii) eliminate indirect land use change (“iLUC”) from CI calculations; (iii) prohibit negative emissions rates except in limited circumstances; (iv) include anti‑abuse and prohibited foreign entity provisions; (v) allow credit eligibility for fuel sold through intermediaries and, in certain circumstances, related parties; and (vi) require use of the most current Treasury‑approved 45Z‑GREET lifecycle analysis model. The final form of these regulations, including future updates to the 45Z‑GREET model and integration of regenerative agricultural practices, may or may not reflect the guidance in the proposed regulations and could materially impact the value of the credit and our ability to benefit from it. The IRA also expanded the carbon capture and sequestration credit under Section 45Q of the Internal Revenue Code to $85 per metric ton of carbon dioxide permanently sequestered. However, Section 45Q credits generally cannot be claimed on the same emissions reductions used to calculate Section 45Z credits, which may affect the economics and timing of carbon capture investments. The RFS sets a floor for biofuels use in the United States. In March 2026, the EPA finalized RVOs for 2026 and 2027 (RFS "Set 2"), setting the implied conventional ethanol levels at 15 billion gallons for 2026 and 2027. The EPA also finalized an increase in biomass based diesel volumes setting the volumes at 5.4 billion for 2026 and 5.7 billion for 2027. The EPA's proposal that any foreign produced fuel or fuel produced with foreign feedstocks would only generate 50% of the RIN value did not make it in the final rule. Instead, the EPA indicated this provision would be incorporated into the 2028 RVO. The final RVO includes 70% reallocation of volumes previously waived by SREs. Under the RFS, RINs impact supply and demand. The EPA assigns individual refiners, blenders, and importers the volume of renewable fuels they are obligated to use in each annual RVO based on their percentage of total production of domestic transportation fuel sales. Obligated parties use RINs to show compliance with the RFS mandated volumes. Ethanol producers assign RINs to each gallon of renewable fuel they produce and the RINs are detached when the renewable fuel is blended with transportation fuel domestically. Market participants can trade the detached RINs in the open market. The market price of detached RINs can affect the price of ethanol in certain markets and can influence purchasing decisions by obligated parties. SREs can reduce or waive entirely the obligation for a refinery, which has the practical effect of reducing the RVO, and by extension the number of RINs that need to be retired, which can impact their values and ultimately blending levels of renewable fuels. There are multiple on-going legal challenges to how the EPA has handled SREs and RFS rulemakings. In June 2025, the U.S. Supreme Court ruled that legal challenges to EPA RFS decisions must be brought exclusively in the U.S. Court of Appeals for the District of Columbia, resolving prior conflicting appellate court decisions and limiting venue selection in future RFS litigation. On May 28, 2026, several environmental groups filed a lawsuit challenging RFS “Set 2” rule, claiming the EPA failed to properly account for the environmental impacts of crop-based biofuel. On May 29, 2026, the American Fuel & Petrochemical Manufacturers Association filed a lawsuit challenging the 2026-2027 RVOs citing increased compliance costs. On June 1, 2026, the Renewable Natural Gas Coalition filed a lawsuit challenging the EPA’s decision to partially waive the cellulosic RVO in the RFS “Set 2” rule. The U.S. Court of Appeals for the District of Columbia quickly consolidated these lawsuits by June 3, 2026. While these lawsuits were an expected outcome of the most recent “Set 2” rule, ongoing litigation and future EPA policy regarding SREs could continue to impact RFS implementation and market dynamics. The One-Pound Waiver, which was extended in May 2019 to allow E15 to be sold year-round to all vehicles model year 2001 and newer, was challenged in an action filed in Federal District Court for the D.C. Circuit. On July 2, 2021, the Circuit Court vacated the EPA’s rule so the future of summertime, defined as June 1 to September 15, sales of E15 is uncertain. The Supreme Court subsequently declined to hear a challenge to this ruling. In 2022, the EPA issued emergency waivers to allow for the continued sale of E15 during the summer months and similar summertime waivers have been issued each year since then, with the 2026 driving season marking the eighth consecutive year that E15 is able to be sold 38 Table of Contents year-round nationwide. The EPA has also allowed for the elimination of the One-Pound Waiver for E10 in several Midwestern states, which would have the practical effect of allowing for E15 to be sold year-round in the following states: Illinois, Iowa, Minnesota, Missouri, Nebraska, Ohio, South Dakota and Wisconsin. Legislation to resolve this issue has been introduced multiple times over the past five years. In December 2024, a provision to permanently authorize nationwide year-round sales of E15 was included in a government spending bill but was subsequently removed prior to enactment. In early 2026, legislation to authorize year-round nationwide sales of E15 was expected to be included in the Farm Bill but was ultimately removed prior to House passage. On May 13, 2026, the U.S. House of Representatives passed the Nationwide Consumer and Fuel Retailer Choice Act, legislation that would permit nationwide year-round sales of E15 and would also amend certain provisions of the Renewable Fuel Standard. As of July 31, 2026, year-round E15 provisions were reintroduced for consideration as part of ongoing Farm Bill negotiations, providing an additional potential legislative pathway to permanently authorize nationwide year-round sales of E15. Although the current Administration has signaled it would sign E15 legislation into law, the future of a legislative fix to summertime E15 remains uncertain as it must pass both chambers of Congress. A string of 2024 U.S. Supreme Court decisions, namely Loper Bright Enterprises v. Raimondo, SEC v. Jarkesy and Corner Post, Inc. v. Board of Governors of the Federal Reserve, have redefined the power of federal agencies, as well as overturned the important principle of administrative law called "Chevron deference," based on a landmark case, Chevron U.S.A., Inc. v. Natural Resources Defense Council, Inc. The Chevron deference was a doctrine of judicial deference to administrative interpretations. The general shift in power from agencies to the judicial system resulting from these decisions could impact various regulatory rules affecting our business in ways that could affect our business, prospects and operations, and our financial performance positively or negatively. During 2025 and 2026, the United States implemented a series of tariff actions affecting imports from numerous trading partners, and the Office of the U.S. Trade Representative ("USTR") initiated a Section 301 investigation into certain Brazilian trade practices, including ethanol market access. In July 2026, USTR announced the imposition of additional tariffs on most imports from Brazil, citing, among other factors, Brazil's treatment of U.S. ethanol imports. These actions may affect global ethanol trade flows and the relative competitiveness of imported and exported ethanol. In addition, the United States-Mexico-Canada Agreement ("USMCA"), which governs a significant portion of North American trade, entered its scheduled six-year review process in 2026. On July 1, 2026, the United States declined to agree to a 16-year extension of USMCA in its current form, triggering annual joint reviews of the agreement through 2036, although the agreement remains in effect. These developments, including the potential renegotiation of certain USMCA provisions and changes in trade relations with Canada, a significant export market for U.S. ethanol, may affect global ethanol trade flows and the relative competitiveness of imported and exported ethanol. The company continues to monitor developments related to U.S. trade policy, tariffs, USMCA negotiations and potential retaliatory measures that could impact domestic and international markets for ethanol and related agricultural products. Environmental and Other Regulation Our operations are subject to environmental regulations, including those that govern the handling and release of ethanol, crude oil and other liquid hydrocarbon materials. Compliance with existing and anticipated environmental laws and regulations may increase our overall cost of doing business, including capital costs to construct, maintain, operate and upgrade equipment and facilities. Our business may also be impacted by domestic and foreign government policies, such as incentives, tariffs, duties, subsidies, import and export restrictions and outright embargos. Comparability There are various events that could affect comparability of our operating results, including fluctuations in our production rates in 2026 compared to 2025, primarily driven by the disposition of our Obion, Tennessee plant in September of 2025, the ceasing of a third-party ethanol marketing agreement effective April 1, 2025, the recognition of Section 45Z production tax credits in 2026, which were not recorded until the third quarter of 2025, and restructuring costs recorded in 2025. Segment Results We report the financial and operating performance for the following two operating segments: (1) ethanol production, which includes the production, storage, and transportation of ethanol, distillers grains, Ultra-High Protein at four plants, and renewable corn oil, in addition to CCS operations at our three Nebraska plants, and (2) agribusiness and energy services, which includes grain handling and storage, commodity marketing and merchant trading for company-produced and third-party ethanol, distillers grains, renewable corn oil, natural gas and other commodities. 39 Table of Contents Corporate activities include selling, general and administrative expenses, consisting primarily of compensation, professional fees and overhead costs not directly related to a specific operating segment. During the normal course of business, our operating segments do business with each other. For example, our agribusiness and energy services segment procures grain and natural gas and sells products, including ethanol, distillers grains, Ultra-High Protein, and renewable corn oil of our ethanol production segment. These intersegment activities are treated like third-party transactions with origination, marketing and storage fees charged at estimated market values. Consequently, these transactions affect segment performance; however, they do not impact our consolidated results since the revenues and corresponding costs are eliminated. When we evaluate segment performance, we review the following segment information as well as earnings before interest expense, income taxes, depreciation and amortization, or EBITDA, and adjusted EBITDA. The selected operating segment financial information is as follows (in thousands): Three Months Ended June 30, % Variance Six Months Ended June 30, % Variance 2026 2025 2026 2025 Revenues Ethanol production Revenues from external customers $ 410,768 $ 526,954 (22.0)% $ 804,127 $ 1,024,412 (21.5)% Intersegment revenues — 199 (100.0) — 513 (100.0) Total segment revenues 410,768 527,153 (22.1) 804,127 1,024,925 (21.5) Agribusiness and energy services Revenues from external customers 35,456 25,875 37.0 87,901 129,932 (32.3) Intersegment revenues 4,090 5,656 (27.7) 10,250 11,428 (10.3) Total segment revenues 39,546 31,531 25.4 98,151 141,360 (30.6) Revenues including intersegment activity 450,314 558,684 (19.4) 902,278 1,166,285 (22.6) Intersegment eliminations (4,090) (5,855) (30.1) (10,250) (11,941) (14.2) $ 446,224 $ 552,829 (19.3)% $ 892,028 $ 1,154,344 (22.7)% Three Months Ended June 30, % Variance Six Months Ended June 30, % Variance 2026 2025 2026 2025 Cost of goods sold Ethanol production (1) (2) $ 306,539 $ 493,663 (37.9)% $ 628,170 $ 997,127 (37.0)% Agribusiness and energy services 30,745 23,451 31.1 73,132 124,549 (41.3) Intersegment eliminations (4,090) (5,855) (30.1) (10,250) (11,941) (14.2) $ 333,194 $ 511,259 (34.8)% $ 691,052 $ 1,109,735 (37.7)% Three Months Ended June 30, % Variance Six Months Ended June 30, % Variance 2026 2025 2026 2025 Gross margin Ethanol production (1) (2) $ 104,229 $ 33,490 * $ 175,957 $ 27,798 * Agribusiness and energy services 8,801 8,080 8.9 25,019 16,811 48.8 $ 113,030 $ 41,570 171.9% $ 200,976 $ 44,609 * 40 Table of Contents Three Months Ended June 30, % Variance Six Months Ended June 30, % Variance 2026 2025 2026 2025 Depreciation and amortization Ethanol production $ 22,673 $ 22,918 (1.1)% $ 45,891 $ 43,953 4.4% Agribusiness and energy services (3) 31 3,860 (99.2) 62 4,458 (98.6) Corporate activities 745 782 (4.7) 1,133 1,536 (26.2) $ 23,449 $ 27,560 (14.9)% $ 47,086 $ 49,947 (5.7)% Three Months Ended June 30, % Variance Six Months Ended June 30, % Variance 2026 2025 2026 2025 Operating income (loss) Ethanol production (2) (4) (5) $ 70,977 $ (12,218) * $ 110,399 $ (51,768) * Agribusiness and energy services (3) 6,699 849 * 20,531 3,282 * Corporate activities (6) (7) (9,802) (16,994) (42.3) (18,284) (42,137) (56.6) $ 67,874 $ (28,363) * $ 112,646 $ (90,623) * (1)Ethanol production includes $60.4 million and $116.5 million of Section 45Z production tax credits net of discounts and other costs for the three and six months ended June 30, 2026, recorded as a reduction of cost of goods sold. (2)Ethanol production includes margins from a one-time sale of accumulated RINs of $22.6 million for the three and six months ended June 30, 2025. (3)Depreciation and amortization for agribusiness and energy services includes impairment of property and equipment of $3.1 million for the three and six months ended June 30, 2025. (4)Ethanol production includes $58.7 million and $113.9 million of 45Z production tax credits recorded net of discounts, other costs and selling, general and administrative expenses for the three and six months ended June 30, 2026, respectively. (5)Ethanol production includes impairment of assets held for sale of $10.7 million for the three and six months ended June 30, 2025. (6)Corporate activities includes $1.7 million and $12.0 million of restructuring costs for the three and six months ended June 30, 2025 as a result of the company's cost reduction initiative, including severance related to the departure of its former CEO. (7)Corporate activities include a pretax loss on sale of assets of $4.0 million for the three and six months ended June 30, 2025. We use EBITDA, adjusted EBITDA, and segment EBITDA as measures of profitability to compare the financial performance of our reportable segments and manage those segments. EBITDA is defined as earnings before interest expense, income taxes, depreciation and amortization excluding the amortization of right-of-use assets and debt issuance costs. Adjusted EBITDA includes adjustments related to restructuring costs, loss on sale of assets, impairment of assets held for sale, loss on sale of equity method investment and our proportional share of EBITDA adjustments of our equity method investees. We believe EBITDA, adjusted EBITDA and segment EBITDA are useful measures to compare our performance against other companies. These measures should not be considered an alternative to, or more meaningful than, net income, which is prepared in accordance with GAAP. EBITDA, adjusted EBITDA, and segment EBITDA calculations may vary from company to company. Accordingly, our computation of EBITDA, adjusted EBITDA, and segment EBITDA may not be comparable with a similarly titled measure of other companies. 41 Table of Contents The following table reconciles net income (loss) including noncontrolling interest to adjusted EBITDA (in thousands): Three Months Ended June 30, % Variance Six Months Ended June 30, % Variance 2026 2025 2026 2025 Net income (loss) $ 67,206 $ (72,227) * $ 100,671 $ (144,868) * Interest expense 8,130 13,899 (41.5) 19,615 22,812 (14.0) Income tax (benefit) expense, net of equity method income taxes (5,485) 1,885 * (2,569) 1,720 * Depreciation and amortization (1) 23,449 27,560 (14.9) 47,086 49,947 (5.7) EBITDA 93,300 (28,883) * 164,803 (70,389) * Restructuring costs — 2,520 * — 19,106 * Loss on sale of assets — 4,044 * — 4,044 * Impairment of assets held for sale — 10,724 * — 10,724 * Loss on sale of equity method investment — 26,987 * 26,987 * Proportional share of EBITDA adjustments to equity method investees 45 1,050 (95.7) 90 1,828 (95.1) Adjusted EBITDA $ 93,345 $ 16,442 * $ 164,893 $ (7,700) * (1)Excludes amortization of operating lease right-of-use assets and amortization of debt issuance costs. The following table reconciles segment EBITDA to consolidated adjusted EBITDA (in thousands): Three Months Ended June 30, % Variance Six Months Ended June 30, % Variance 2026 2025 2026 2025 Adjusted EBITDA Ethanol production (1) (2) (3) $ 94,454 $ 8,992 * $ 157,510 $ (10,424) * Agribusiness and energy services 6,924 5,028 37.7 20,935 8,184 155.8 Corporate activities (4) (8,078) (42,903) (81.2) (13,642) (68,149) (80.0) EBITDA 93,300 (28,883) * 164,803 (70,389) * Restructuring costs — 2,520 * — 19,106 * Loss on sale of assets — 4,044 * — 4,044 * Impairment of assets held for sale — 10,724 * — 10,724 * Loss on sale of equity method investment — 26,987 * — 26,987 * Proportional share of EBITDA adjustments to equity method investees 45 1,050 (95.7) 90 1,828 (95.1) $ 93,345 $ 16,442 * $ 164,893 $ (7,700) * (1)Ethanol production includes $58.7 million and $113.9 million of 45Z production tax credits recorded net of discounts, other costs and selling, general and administrative expenses for the three and six months ended June 30, 2026, respectively. (2)Ethanol production includes margins from a one-time sale of accumulated RINs of $22.6 million for the three and six months ended June 30, 2025. (3)Ethanol production includes impairment of assets held for sale of $10.7 million for the three and six months ended June 30, 2025. (4)Corporate activities include a pretax loss on sale of assets of $4.0 million and a pretax loss on sale of equity method investment of $27.0 million for the three and six months ended June 30, 2025, respectively. * Percentage variance not considered meaningful. 42 Table of Contents Three Months Ended June 30, 2026 Compared with the Three Months Ended June 30, 2025 Consolidated Results Consolidated revenues decreased $106.6 million for the three months ended June 30, 2026 compared with the same period in 2025, primarily due to lower revenues within our ethanol production segment as a result of lower volumes sold primarily driven by the disposition of our Obion, Tennessee plant. Net income increased $139.4 million and adjusted EBITDA increased $76.9 million for the three months ended June 30, 2026 compared with the same period last year primarily due to recognition of $58.7 million of Section 45Z production tax credits recorded net of discounts, other costs and selling, general and administrative expenses, higher margins in our ethanol production and agribusiness and energy services segments and $5.9 million of lower selling, general and administrative expenses primarily as a result of restructuring costs of $2.5 million incurred during the three months ended June 30, 2025. Interest expense decreased $5.8 million for the three months ended June 30, 2026 compared with the same period in 2025 primarily due to prior year loan fees related to the issuance and modification of warrants in conjunction with access to a short-term line of credit and an amendment on our Junior Notes, offset by higher debt balances associated with carbon sequestration equipment. Income tax benefit was $5.5 million for the three months ended June 30, 2026, compared with income tax expense of $2.3 million for the same period in 2025 primarily due to changes in the valuation allowance on deferred tax assets, offset by an increase in pre-tax book income from the generation of non-taxable 45Z production tax credits. The following discussion provides greater detail about our second quarter segment performance. Ethanol Production Segment Key operating data for our ethanol production segment is as follows: Three Months Ended June 30, 2026 2025 % Variance Ethanol (gallons) 160,700 193,571 (17.0)% Distillers grains (equivalent dried tons) 323 413 (21.8) Ultra-High Protein (tons) 49 66 (25.8) Renewable corn oil (pounds) 58,332 65,231 (10.6) Corn consumed (bushels) 54,558 65,312 (16.5) Revenues in our ethanol production segment decreased $116.4 million for the three months ended June 30, 2026 compared with the same period in 2025, primarily due to the disposition of our Obion, Tennessee plant resulting in decreased revenues of $60.6 million, decreased ethanol revenues of $11.0 million driven by lower freight revenue and $25.0 million driven by timing of ethanol revenue recognition during the three months ended June 30, 2025 both as a result of our transition to a third party marketing arrangement, a one-time sale of accumulated RINs of $22.6 million during the three months ended June 30, 2025, lower ethanol and distillers grains volumes sold resulting in decreased revenues of $12.3 million and $6.3 million, respectively, decreased revenues as a result of hedging activities of $15.2 million, and lower weighted average selling prices on distillers grains resulting in decreased revenues of $1.2 million, partially offset by higher ethanol and renewable corn oil weighted average selling prices resulting in increased revenues of $15.9 million and $2.0 million, respectively, higher project revenues of $12.2 million and higher renewable corn oil volumes sold resulting in increased revenue of $6.9 million. Cost of goods sold in our ethanol production segment decreased $187.1 million for the three months ended June 30, 2026 compared with the same period last year primarily due to the recognition of $60.4 million of Section 45Z production tax credits net of discounts and other costs, as well as lower corn volumes purchased, lower ethanol volumes purchased, decreased weighted average corn prices, lower freight costs, and hedging activities resulting in decreased costs of $50.5 million, $45.3 million, $21.4 million, $11.2 million, and $1.6 million, respectively. Operating income in our ethanol production segment increased $83.2 million for the three months ended June 30, 2026 compared with the same period in 2025 primarily due to increased margins as outlined above. Depreciation and 43 Table of Contents amortization expense for the ethanol production segment was $22.7 million for the three months ended June 30, 2026, compared with $22.9 million for the same period last year. Agribusiness and Energy Services Segment Revenues in our agribusiness and energy services segment increased $8.0 million while operating income increased $5.9 million for the three months ended June 30, 2026, compared with the same period in 2025. The increase in revenues was primarily due to increased ethanol trading revenues. The increase in operating income was primarily due to higher natural gas trading margins. Intersegment Eliminations Intersegment eliminations of revenues decreased by $1.8 million for the three months ended June 30, 2026 primarily due to decreased marketing and corn origination fees paid to the agribusiness and energy services segment as a result of lower volumes processed. Corporate Activities Operating loss was impacted by an decrease in corporate activities of $7.2 million for the three months ended June 30, 2026 compared with 2025 primarily due to higher personnel costs as a result of restructuring in the prior period. Six Months Ended June 30, 2026 Compared with the Six Months Ended June 30, 2025 Consolidated Results Consolidated revenues decreased $262.3 million for the six months ended June 30, 2026 compared with the same period in 2025, primarily due to lower revenues within our ethanol production segment as a result of lower volumes sold primarily driven by the disposition of our Obion, Tennessee plant, as well as lower revenues in our agribusiness and energy services segment as a result of the company ceasing a third-party marketing agreement with Tharaldson Ethanol Plant I LLC effective April 1, 2025. Net income increased $245.5 million and adjusted EBITDA increased $172.6 million for the six months ended June 30, 2026 compared with the same period last year primarily due to recognition of $113.9 million of Section 45Z production tax credits recorded net of discounts, other costs and selling, general and administrative expenses, higher margins in our ethanol production and agribusiness and energy services segments and $29.3 million of lower selling, general and administrative expenses primarily as a result of restructuring costs of $19.1 million incurred during the six months ended June 30, 2025. Interest expense decreased $3.2 million for the six months ended June 30, 2026 compared with the same period in 2025 primarily due to prior year loan fees related to the issuance and modification of warrants in conjunction with access to a short-term line of credit and an amendment on our Junior Notes, partially offset by higher debt balances associated with carbon sequestration equipment. Income tax benefit was $2.6 million for the six months ended June 30, 2026, compared with income tax expense of $2.4 million for the same period in 2025 primarily due to changes in the valuation allowance on deferred tax assets, offset by an increase in pre-tax book income from the generation of non-taxable 45Z production tax credits. The following discussion provides greater detail about our second quarter segment performance. 44 Table of Contents Ethanol Production Segment Key operating data for our ethanol production segment is as follows: Six Months Ended June 30, 2026 2025 % Variance Ethanol (gallons) 334,896 388,899 (13.9)% Distillers grains (equivalent dried tons) 685 830 (17.5) Ultra-High Protein (tons) 103 134 (23.1) Renewable corn oil (pounds) 116,808 129,494 (9.8) Corn consumed (bushels) 113,360 131,576 (13.8) Revenues in our ethanol production segment decreased $220.8 million for the six months ended June 30, 2026 compared with the same period in 2025, primarily due to the disposition of our Obion, Tennessee plant resulting in decreased revenues of $127.4 million, decreased ethanol revenues of $47.1 million driven by lower freight revenue and $33.7 million driven by timing of ethanol revenue recognition during the six months ended June 30, 2025 both as a result of our transition to a third party marketing arrangement, decreased revenues as a result of hedging activities of $27.5 million, a one-time sale of accumulated RINs of $22.6 million during the six months ended June 30, 2025, and lower distillers grains volumes sold resulting in decreased revenues of $6.1 million, partially offset by higher project revenues of $17.2 million, higher renewable corn oil and distillers grains weighted average selling prices resulting in increased revenues of $15.7 million and $2.0 million, respectively, and higher corn oil volumes sold resulting in increased revenues of $2.3 million. Cost of goods sold in our ethanol production segment decreased $369.0 million for the six months ended June 30, 2026 compared with the same period last year primarily due to the recognition of $116.5 million of Section 45Z production tax credits net of discounts and other costs, as well as lower corn volumes purchased, lower ethanol volumes purchased, lower freight costs, decreased weighted average corn prices, and hedging activities resulting in decreased costs of $86.4 million, $69.3 million, $48.5 million, $45.6 million and $9.1 million, respectively. Operating income in our ethanol production segment increased $162.2 million for the six months ended June 30, 2026 compared with the same period in 2025 primarily due to increased margins as outlined above. Depreciation and amortization expense for the ethanol production segment was $45.9 million for the six months ended June 30, 2026, compared with $44.0 million for the same period last year, with the increase driven by carbon sequestration equipment placed in service during the fourth quarter of 2025. Agribusiness and Energy Services Segment Revenues in our agribusiness and energy services segment decreased $43.2 million while operating income increased $17.2 million for the six months ended June 30, 2026, compared with the same period in 2025. The decrease in revenues was primarily due to the company ceasing a third-party marketing agreement with Tharaldson Ethanol Plant I LLC effective April 1, 2025, offset by higher natural gas revenues. The increase in operating income was primarily due to higher natural gas trading margins. Intersegment Eliminations Intersegment eliminations of revenues decreased by $1.7 million for the six months ended June 30, 2026 primarily due to decreased marketing and corn origination fees paid to the agribusiness and energy services segment as a result of lower volumes processed. Corporate Activities Operating loss was impacted by an decrease in corporate activities of $23.9 million for the six months ended June 30, 2026 compared with 2025 primarily due to higher personnel costs as a result of restructuring in the prior period. 45 Table of Contents Liquidity and Capital Resources Our principal sources of liquidity include cash generated from operating activities and bank credit facilities. We fund our operating expenses and service debt primarily with operating cash flows. Capital resources for maintenance and growth expenditures are funded by a variety of sources, including cash generated from operating activities, borrowings under credit facilities, or issuance of public or private debt or equity securities. Our ability to access capital markets for debt under reasonable terms depends on our financial condition, credit ratings and market conditions. We believe that our ability to obtain financing at reasonable rates based on these factors remains sufficient and provides a solid foundation to meet our future liquidity and capital resource requirements. On June 30, 2026, we had $185.4 million in cash and cash equivalents and $57.7 million in restricted cash. We also had $290.0 million available under our committed revolving credit agreement, subject to restrictions or other lending conditions. Total corporate liquidity consisting of unrestricted cash, distributable cash from subsidiaries and credit facility availability was $196.4 million as of June 30, 2026. Funds at certain subsidiaries are generally required for their ongoing operational needs and restricted from distribution. At June 30, 2026, our subsidiaries had approximately $44.0 million of net assets that were not available to use in the form of dividends, loans or advances due to restrictions contained in their credit facilities. On April 17, 2026, the Revolver Facility was amended by the Second Amendment to the Loan and Security Agreement and the borrowing limit was reduced from $350 million to $300 million which reduced our availability under the committed revolving credit agreement. Net cash provided by operating activities was $46.8 million for the six months ended June 30, 2026, compared with net cash provided by operating activities of $3.8 million for the same period in 2025. Net cash provided by operating activities compared to the prior year increased primarily due to higher net income and changes in derivative financial instruments partially offset by working capital changes related to production tax credits, inventories and accounts payable. Net cash used in investing activities was $15.1 million for the six months ended June 30, 2026, compared with net cash used in investing activities of $32.3 million for the same period in 2025. Investing activities were primarily affected by lower capital expenditures in the current period. Net cash used in financing activities was $18.7 million for the six months ended June 30, 2026, compared with net cash used in financing activities of $28.1 million for the same period in 2025, primarily due higher net payments on short-term borrowings in 2025 offset by proceeds from a product financing arrangement in 2025. Additionally, Green Plains Finance Company, Green Plains Trade, Green Plains Grain and Green Plains Commodity Management use revolving credit facilities to finance working capital requirements. We frequently draw from and repay these facilities, which results in significant cash movements reflected on a gross basis within financing activities as proceeds from and payments on short-term borrowings. We incurred net capital expenditures of approximately $17.1 million during the six months ended June 30, 2026, primarily for various capital projects. The current projected estimate for capital spending related to maintenance, environmental, health and safety is approximately $10 million to $15 million for the remainder of 2026, which is subject to review prior to the initiation of any project, and expected to be financed with cash on hand and with cash provided by operating activities. We expect additional capital spending related to efficiency projects during the remainder of 2026 of $20 million to $25 million, primarily for the addition of a grain storage building at our Wood River facility. The company financed the CCS projects at its three Nebraska plants. The payments have commenced and the company is estimating annualized payments to total $17.1 million in 2026. The company generated $58.7 million and $113.9 million of EBITDA resulting from Section 45Z production tax credits net of discounts and other costs during the three and six months ended June 30, 2026, respectively. Estimated based on the current production outlook, eligible gallons, and expected sales of the production tax credits, the company expects to generate between $200 million and $225 million of EBITDA from the generation of 45Z production tax credits for the year ended December 31, 2026. This is subject to change based on actual production volumes, CI factors at eligible plants, and the final sales price of production tax credits generated in 2026. Our business is sensitive to the price of commodities, particularly for corn, ethanol, distillers grains, Ultra-High Protein, renewable corn oil and natural gas. We use derivative financial instruments to reduce the market risk associated with fluctuations in commodity prices. Sudden changes in commodity prices may require cash deposits with brokers for margin calls or significant liquidity with little advanced notice to meet margin calls, depending on our open derivative positions. We continuously monitor our exposure to margin calls and believe we will continue to maintain adequate liquidity to cover margin calls from our operating results and borrowings. 46 Table of Contents In August 2014 and October 2019, our Board authorized a share repurchase program of up to $200.0 million of our common stock. Under the program, we may repurchase shares in open market transactions, privately negotiated transactions, accelerated share buyback programs, tender offers or by other means. The timing and amount of repurchase transactions are determined by our management based on market conditions, share price, legal requirements and other factors. The program may be suspended, modified or discontinued at any time without prior notice. Since inception of the repurchase program, we have repurchased 10.3 million shares of common stock for approximately $122.8 million under the program. We did not repurchase any shares of common stock during the second quarter of 2026. We believe we have sufficient working capital for our existing operations. A continued sustained period of unprofitable operations, however, may strain our liquidity. We may sell additional assets or equity or borrow capital to improve or preserve our liquidity. Debt We were in compliance with our debt covenants at June 30, 2026. Based on our forecasts, we anticipate we will maintain compliance at each of our subsidiaries for the next twelve months. We cannot provide assurance that actual results will approximate our forecasts or that we will inject the necessary capital into a subsidiary to maintain compliance with its respective covenants. In the event a subsidiary is unable to comply with its debt covenants, the subsidiary’s lenders may determine that an event of default has occurred, and following notice, the lenders may terminate the commitment and declare the unpaid balance due and payable. Corporate Activities In March 2021, we issued $230.0 million of unsecured 2.25% convertible senior notes due in 2027 (the "2027 Notes"). The 2027 Notes bear interest at a rate of 2.25% per year, payable on March 15 and September 15 of each year. The initial conversion rate is 31.6206 shares of our common stock per $1,000 principal amount of 2027 Notes (equivalent to an initial conversion price of approximately $31.62 per share of our common stock), representing an approximately 37.5% premium over the offering price of our common stock. The conversion rate is subject to adjustment upon the occurrence of certain events, including but not limited to; the event of a stock dividend or stock split; the issuance of additional rights, options and warrants; spinoffs; or a tender or exchange offering. In addition, we may be obligated to increase the conversion rate for any conversion that occurs in connection with certain corporate events, including our calling the 2027 Notes for redemption. We may settle the 2027 Notes in cash, common stock or a combination of cash and common stock. We plan to settle the 2027 Notes with cash generated from operating activities upon maturity. On October 27, 2025, the company executed separate, privately negotiated exchange agreements with certain of the holders of its existing 2027 Notes to exchange (the “exchange transactions”) $170 million aggregate principal amount of the 2027 Notes for $170 million of newly issued 5.25% Convertible Senior Notes due November 2030 (the “2030 Notes”). Additionally, the company completed separate, privately negotiated subscription agreements pursuant to which it issued $30 million of 2030 Notes for $30 million in cash (the “subscription transactions”). The 2030 Notes bear interest at a rate of 5.25% per year, payable on May 1 and November 1 of each year, beginning May 1, 2026. The 2030 notes are general unsecured obligations of the company. The initial conversion rate of the 2030 Notes is 63.6132 shares of common stock per $1,000 principal amount of 2030 Notes (equivalent to an initial conversion price of approximately $15.72 per share of common stock, which represents a conversion premium of approximately 50% over the offering price of our common stock), and is subject to customary anti-dilution adjustments. At June 30, 2026, the outstanding principal balances on the remaining 2027 Notes and the 2030 Notes were $60.0 million and $200.0 million, respectively. Ethanol Production Segment Green Plains Shenandoah, a wholly-owned subsidiary, has a $75.0 million secured loan agreement, which matures on September 1, 2035. At June 30, 2026, the outstanding principal balance was $69.4 million on the loan and the interest rate was 5.77%. On and after July 24, 2023, Green Plains Central City Capture Company LLC, Green Plains Wood River Capture Company LLC, and Green Plains York Capture Company LLC, (collectively, the "capture companies") which are all wholly-owned subsidiaries of the company, entered into a series of agreements with Tallgrass High Plains Carbon Storage, LLC ("Tallgrass") and its affiliates to finance, construct and operate carbon capture, transportation and sequestration assets associated with the company’s Central City, Wood River, and York ethanol facilities in Nebraska. Under the agreements, the capture companies are obligated to repay Tallgrass all costs associated with the construction of the carbon capture and compression facilities over a 144-month delivery period. The payment structure is designed to provide Tallgrass with a 9% pretax, unlevered internal rate of return ("IRR") on its investment. All projects met criteria for substantial completion and 47 Table of Contents are classified as debt. The total estimated value of this debt recorded on the balance sheet is $125.3 million. Repayments commenced in January 2026. This debt is secured by substantially all real and personal property interests associated with the capture companies. Green Plains Inc. further supports the obligation through a guaranty, under which it unconditionally guarantees the capture companies' performance and payment obligations. The capture companies may pre-repay the obligation early by providing Tallgrass at least ninety (90) days’ prior written notice and remitting the prepayment, which represents the amount required for Tallgrass to achieve its contracted 9% pretax, unlevered IRR on its investments. We also have small equipment financing loans, finance leases on equipment or facilities, and other forms of debt financing. Agribusiness and Energy Services Segment Green Plains Finance Company, Green Plains Grain and Green Plains Trade had total senior secured revolving commitments of $300.0 million and an accordion feature whereby amounts available under the Facility may be increased by up to $100.0 million of new lender commitments subject to certain conditions. Each SOFR rate loan shall bear interest for each day at a rate per annum equal to the Term SOFR rate for the outstanding period plus a Term SOFR adjustment and an applicable margin of 2.25% to 2.50%, which is dependent on undrawn availability under the facility. Each base rate loan shall bear interest at a rate per annum equal to the base rate plus the applicable margin of 1.25% to 1.50%, which is dependent on undrawn availability under the Facility. The unused portion of the Facility is also subject to a commitment fee of 0.275% to 0.375%, dependent on undrawn availability. At June 30, 2026, the outstanding principal balance was $10.0 million on the facility and the interest rate was 6.24%. On April 17, 2026, the Facility was further amended by the Second Amendment to the Loan and Security Agreement (the “Second Revolver Amendment”). The Second Revolver Amendment (i) extended the termination date of the Facility from March 25, 2027 to September 25, 2027 and (ii) reduced the size of the Facility commitment from $350 million to $300 million. Green Plains Commodity Management has an uncommitted $20.0 million secured revolving credit facility to finance margins related to its hedging programs that matures on April 30, 2028. Advances are subject to variable interest rates equal to SOFR plus 1.75%. At June 30, 2026, the outstanding principal balance was $17.0 million on the facility and the interest rate was 5.34%. Green Plains Grain has a short-term inventory financing agreement with a financial institution. The company has accounted for the agreement as short-term notes, rather than revenues, and has elected the fair value option to offset fluctuations in market prices of the inventory. This agreement is subject to negotiated variable interest rates. The company had no outstanding short-term notes payable related to the inventory financing agreement as of June 30, 2026. Refer to Note 8 - Debt in the notes to the consolidated financial statements included herein for more information about our debt. Effects of Inflation We have experienced inflationary impacts on labor costs, wages, components, equipment, other inputs and services across our business, many of which are beyond our control, and inflation and its impact could escalate in future quarters. Moreover, we have fixed price arrangements with our customers and are not able to pass those costs along in most instances. As such, inflationary pressures could have a material adverse effect on our performance and financial statements. Contractual Obligations and Commitments In addition to debt, our material future obligations include certain lease agreements and contractual and purchase commitments related to commodities, storage and transportation. Aggregate minimum lease payments under the operating lease agreements for future fiscal years as of June 30, 2026 totaled $71.3 million. As of June 30, 2026, we had contracted future purchases of grain, distillers grains and natural gas valued at approximately $204.3 million, future commitments for storage and transportation valued at approximately $32.9 million, and accumulated commitments related to the construction of carbon capture and sequestration equipment at our three Nebraska plants of $12.4 million. Refer to Note 13 – Commitments and Contingencies included in the notes to consolidated financial statements for more information. Critical Accounting Policies and Estimates Critical accounting policies, including those relating to derivative financial instruments and accounting for income taxes, are impacted significantly by judgments, assumptions and estimates used in the preparation of the consolidated 48 Table of Contents financial statements. Information about our critical accounting policies and estimates are included in our annual report on Form 10-K for the year ended December 31, 2025. Accounting for Section 45Z Production Tax Credits During the first quarter of 2026, the company elected to early adopt ASU 2025-10, Accounting for Government Grants Received by Business Entities. Concurrently, the company elected to change its accounting policy related to the recognition of Section 45Z clean fuel production tax credits. Under this new policy, the recognition of the production tax credits occurs when the ethanol is produced, which is when compliance with the 45Z tax credit conditions is deemed probable. We recognize the Section 45Z production tax credits at fair value, which is determined by the expected transfer price of the credits. The production tax credits are recognized as current assets in the consolidated balance sheets and as a reduction of cost of goods sold in the consolidated statements of operations. Off-Balance Sheet Arrangements We do not have any off-balance sheet arrangements.