Green Plains Inc. 2025 Annual Report
2025
Annual
Report
Who
We Are
Green Plains is a leading biorefining
company focused on disciplined
execution and leadership in
low‑carbon biofuels and high‑value
ingredients. We operate an integrated,
performance‑driven platform designed
to maximize yield, lower carbon intensity,
and deliver value through our core
operations.
How we operate is central to how we create
value. Every investment must reinforce our
leadership in low‑carbon biofuels and strengthen
our position in high‑value ingredients across
the broader industry. Guided by a strong
safety culture, operational excellence, rigorous
measurement, and continuous improvement, we
focus on responsible capital deployment and
consistent, long‑term performance.
Forward-Looking Statement
This annual report contains “forward-looking
statements” within the meaning of the federal securities
laws. See the discussion under “Cautionary Statement
Regarding Forward-Looking Statements” in our 2025
Form 10-K for matters to be considered in this regard.
9 Biorefineries
287 Million
Approximately 640
Strategically located throughout the United States
Bushels of annual corn consumption capacity
Dedicated employees
Green Plains Inc. 2025 Annual Report
Letter from Our
Chief Executive Officer
Dear Shareholders,
Green Plains is operating at a different level
than it was just a few years ago. The progress
we delivered in 2025 reflects a clear shift—
inclusive of strategy and execution, with laser
focus on performance. We set priorities, held
ourselves accountable, and delivered results.
That progress starts with our people. I want
to thank the Green Plains team for their
focus and discipline throughout the year, our
Board for its confidence and oversight, and
our shareholders for their continued trust.
The results reflect a team that executed with
discipline and operated to the high standards
we expect, including a strong safety record
across the fleet.
Today, the Green
Plains team is
focused. We are
clear about what
creates value and
what does not.
Execution That Changed the
Profile of the Business
2025 was a year where execution showed up
clearly across our operations. Four plants reached
historic production volumes. Seven delivered record
ethanol yields. Protein and renewable corn oil yields
continued to improve across the fleet. This level of
performance is now being delivered consistently.
As a result of sustained operating gains, we
increased the stated capacity of our operational fleet
to 730 million gallons per year. This update reflects
demonstrated performance, not optimism. Our
plants are doing more with the same assets because
the teams running them are executing better.
This is the outcome of a culture built on
measurement, accountability, and safe, reliable
execution.
Green Plains Inc. 2025 Annual Report
Green Plains Inc. 2025 Annual Report
Decarbonization Built Into
Operations
Another important shift became clear late in 2025:
decarbonization moved from development to
delivery. All three Nebraska plants now have CO2
compression fully operational, with carbon being
permanently sequestered. This lowers carbon
intensity, improves competitiveness, and creates real
economic value.
Carbon is not an add-on to our business—it is
integrated into how we operate our plants. We
continue to believe that low carbon ethanol will play
a critical role in future energy markets, and our early
execution positions Green Plains at the front of that
curve.
We operate our plants efficiently and safely, without
compromise. Decarbonization builds on that
foundation.
A More Disciplined, Better
Positioned Company
Operational performance and cost discipline drove
meaningful improvement in results during 2025. Just
as important, we took decisive actions to strengthen
and derisk the balance sheet—improving flexibility
and positioning Green Plains to allocate capital with
confidence.
Today, the Green Plains team is focused. We are clear
about what creates value and what does not. This
clarity is fundamental to how we operate, how we
invest, and how we manage operating and financial
risk.
Clear Priorities Heading
Into 2026
As we move forward, our priorities are clear. We are
focused on execution, advancing energy efficiency
and carbon intensity reduction projects, evaluating
additional carbon sequestration options, and
advancing opportunities for debottlenecking our
facilities when objective analysis presents returns that
justify investment.
In our company, every project competes for capital.
Every investment must reinforce our leadership in low-
carbon biofuels and across the broader industry.
The progress made in 2025 gives us confidence—
not because the work is finished, but because the
foundation is solid. We know what we are focused on,
and we know how to execute.
I am proud of what our team delivered last year and
confident in where we are headed. Green Plains enters
2026 with momentum, discipline, and a clear path
forward—and we remain committed to delivering
long-term value for our shareholders.
Chris Osowski
President and Chief Executive Officer
The progress made in
2025 gives us confidence—
not because the work is
finished, but because the
foundation is solid.
Green Plains Inc. 2025 Annual Report
Selected
Financial Data
Statement of Operations Data
Year Ended December 31,
(in thousands, except per share information)
2025
2024
2023
Revenues
$ 2,091,680
$ 2,458,796
$ 3,295,743
Costs and expenses
2,158,928
2,506,255
3,357,321
Operating loss
(67,248)
(47,459)
(61,578)
Total other income (expense)
(76,569)
(23,839)
(20,771)
Net loss
(121,000)
(81,189)
(76,299)
Net loss attributable to Green Plains
$ (121,278)
$ (82,497)
$ (93,384)
Earnings per share:
Net loss attributable to Green Plains - basic and diluted
$ (1.80)
$ (1.29)
$ (1.59)
Other Data: (Non-GAAP)
Adjusted EBITDA (unaudited and in thousands)
$ 94,011
$ 18,715
$ 45,506
Year Ended December 31,
(in thousands)
2025
2024
2023
Net loss
$ (121,000)
$ (81,189)
$ (76,299)
Interest expense
76,668
33,095
37,703
Income tax expense (benefit), net of equity method income taxes
(52,419)
5,153
(5,617)
Depreciation and amortization
98,434
90,587
98,244
EBITDA
$ 1,683
$ 47,646
$ 54,031
Restructuring costs
24,341
—
—
Gain on sale of assets, net
(31,535)
(30,723)
(5,265)
Impairment of assets held for sale
14,562
—
—
Other (income) expense
2,025
—
(3,440)
45Z production tax credits
54,161
—
—
Loss on sale of equity method investment
26,856
—
—
Proportional share of EBITDA adjustments to equity method investees
1,918
1,792
180
Adjusted EBITDA
$ 94,011
$ 18,715
$ 45,506
Balance Sheet Data
December 31,
(in thousands)
2025
2024
2023
Cash and cash equivalents
$ 182,319
$ 173,041
$ 349,574
Current assets
482,212
569,032
732,730
Total assets
1,578,396
1,782,174
1,939,322
Current liabilities
268,706
385,687
384,962
Long-term debt
361,992
432,460
491,918
Total liabilities
806,425
907,637
949,266
Stockholders’ equity
$ 771,971
$ 874,537
$ 990,056
The following table reconciles net loss to adjusted EBITDA for the periods indicated:
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
x ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2025
or
o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ____ to _____
Commission file number 001-32924
GREEN PLAINS INC.
(Exact name of registrant as specified in its charter)
Iowa
84-1652107
(State or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification No.)
1811 Aksarben Drive, Omaha, NE 68106
(402) 884-8700
(Address of principal executive offices, including zip code)
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Trading Symbol
Name of each exchange on which registered
Common Stock, par value $0.001 per share
GPRE
The Nasdaq Stock Market LLC
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 o No x
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 o No x
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 x No o
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 x No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting
company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company”
and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer
o
Accelerated filer
x
Non-accelerated filer
o
Smaller reporting company
o
Emerging growth company
o
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. o
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. x
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. o
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 §240.10-1(b). o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes o No x
The aggregate market value of the company’s voting common stock held by non-affiliates of the registrant as of June 30, 2025 (the last
business day of the second quarter), based on the last sale price of the common stock on that date of $6.03, was approximately $388.8
million. For purposes of this calculation, executive officers and directors are deemed to be affiliates of the registrant.
As of February 6, 2026, there were 69,838,844 shares of the registrant’s common stock outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant’s definitive Proxy Statement for the 2026 Annual Meeting of Shareholders are incorporated by reference in Part
III herein. The company intends to file such Proxy Statement with the Securities and Exchange Commission no later than 120 days after the
end of the period covered by this report on Form 10-K.
1
TABLE OF CONTENTS
Page
Commonly Used Defined Terms
2
PART I
Item 1.
Business.
5
Item 1A.
Risk Factors.
14
Item 1B.
Unresolved Staff Comments.
27
Item 1C.
Cybersecurity.
27
Item 2.
Properties.
28
Item 3.
Legal Proceedings.
28
Item 4.
Mine Safety Disclosures.
28
PART II
Item 5.
Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of
Equity Securities.
29
Item 6.
Reserved.
30
Item 7.
Management’s Discussion and Analysis of Financial Condition and Results of Operations.
31
Item 7A.
Quantitative and Qualitative Disclosures About Market Risk.
46
Item 8.
Financial Statements and Supplementary Data.
48
Item 9.
Changes in and Disagreements With Accountants on Accounting and Financial Disclosure.
48
Item 9A.
Controls and Procedures.
48
Item 9B.
Other Information.
50
Item 9C.
Disclosure Regarding Foreign Jurisdictions that Prevent Inspections.
50
PART III
Item 10.
Directors, Executive Officers and Corporate Governance.
50
Item 11.
Executive Compensation.
50
Item 12.
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder
Matters.
50
Item 13.
Certain Relationships and Related Transactions, and Director Independence.
50
Item 14.
Principal Accounting Fees and Services.
50
PART IV
Item 15.
Exhibits, Financial Statement Schedules.
51
Item 16.
Form 10-K Summary.
57
Signatures.
58
2
Commonly Used Defined Terms
Green Plains Inc. and Subsidiaries:
Green Plains Inc.; Green Plains; the company
Green Plains Inc. and its subsidiaries
FQT
Fluid Quip Technologies, LLC
Green Plains Commodity Management
Green Plains Commodity Management LLC
Green Plains Finance Company
Green Plains Finance Company LLC
Green Plains Grain
Green Plains Grain Company LLC
Green Plains Mount Vernon; Mount Vernon
Green Plains Mount Vernon LLC
Green Plains Obion; Obion
Green Plains Obion LLC
Green Plains Partners; the partnership
Green Plains Partners LP
Green Plains Shenandoah; Shenandoah
Green Plains Shenandoah LLC
Green Plains Trade
Green Plains Trade Group LLC
Green Plains Wood River; Wood River
Green Plains Wood River LLC
Accounting Defined Terms:
ASC
Accounting Standards Codification
EBITDA
Earnings before interest expense, income taxes, depreciation and
amortization
EPS
Earnings per share
Exchange Act
Securities Exchange Act of 1934, as amended
GAAP
U.S. Generally Accepted Accounting Principles
Nasdaq
The Nasdaq Global Market
SEC
Securities and Exchange Commission
Securities Act
Securities Act of 1933, as amended
SOFR
Secured Overnight Financing Rate
Industry and Other Defined Terms:
ATJ
Alcohol-to-Jet
BlackRock
Funds and accounts managed by BlackRock
the Board; our Board
Board of Directors of Green Plains Inc.
BTU
British Thermal Units
CARB
California Air Resources Board
CCS
Carbon capture and storage
CFTC
Commodity Futures Trading Commission
CI
Carbon Intensity
COVID-19
Coronavirus Disease 2019
CST™
Clean Sugar Technology™
DOE
Department of Energy
E10
Gasoline blended with up to 10% ethanol by volume
E15
Gasoline blended with up to 15% ethanol by volume
E85
Gasoline blended with up to 85% ethanol by volume
EIA
U.S. Energy Information Administration
EPA
U.S. Environmental Protection Agency
EV
Electric Vehicle
3
FERC
Federal Energy Regulatory Commission
FFV
Flexible-fuel vehicle
FSSC
Food Safety System Certification
GHG
Greenhouse gas
GP Turnkey Tharaldson
GP Turnkey Tharaldson LLC
GREET
Greenhouse gases, Regulated Emissions, and Energy use in Technologies
IRA
Inflation Reduction Act
LCFS
Low Carbon Fuel Standard
Merger
Merger of GPLP Merger Sub LLC, a Delaware limited liability company
and a wholly owned subsidiary of GPLP Holdings Inc., a wholly owned
subsidiary of Green Plains ("Holdings"), with and into the partnership,
with the partnership surviving such merger
Merger Agreement
Certain Agreement and Plan of Merger, dated as of September 16, 2023,
by and among Green Plains Inc., Holdings, GPLP Merger Sub LLC, a
wholly owned subsidiary of Holdings, Green Plains Partners LP, and
Green Plains Holdings LLC, the general partner of the partnership (the
"General Partner")
MmBtu
Million British Thermal Units
mmg
Million gallons
mmgy
Million gallons per year
MSC™
Maximized Stillage Co-products™ produced using process technology
developed by Fluid Quip Technologies
MTBE
Methyl tertiary-butyl ether
OBBB
One Big Beautiful Bill Act
R&D tax credit
Research and development tax credit
REC
Renewable energy certificate
RFS
Renewable Fuels Standard
RIN
Renewable identification number
RVO
Renewable volume obligation
SAF
Sustainable Aviation Fuel
Sequence™
A foundational feed ingredient made from a combination of corn and
yeast protein, concentrated at 60%
SRE
Small refinery exemption
TTB
Alcohol and Tobacco Tax and Trade Bureau
U.S.
United States
USDA
U.S. Department of Agriculture
4
Cautionary Statement Regarding Forward-Looking Statements
The SEC encourages companies to disclose forward-looking information so investors can better understand future
prospects and make informed investment decisions. As such, forward-looking statements are included in this report or
incorporated by reference to other documents filed with the SEC.
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 this report under “Risk Factors” 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.
5
PART I
Item 1. Business.
References to “we,” “us,” “our,” “Green Plains,” or the “company” refer to Green Plains Inc. and its subsidiaries.
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. Today, our focus is on operating safely,
efficiently and cost-effectively while reducing the CI of our products and maintaining financial flexibility to support long
term growth. During the year, under new leadership, the company completed targeted asset sales, strengthened liquidity and
reduced debt, positioning Green Plains to capture value from the next phase of the low-carbon transition. Our streamlined
platform is positioned to create value through our focus on operational excellence, continuous improvement and disciplined
capital allocation.
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 and renewable corn oil at nine biorefineries in Illinois, Indiana, Iowa, Minnesota
and Nebraska. 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 3rd 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.
Business Strategy
Ethanol is a valuable low CI oxygenate that comprises approximately 10.1% of the domestic surface transportation
gasoline supply in the U.S. with the potential to grow with increased offering of higher blends, including E15 and E85.
Additionally, government incentives to produce SAF through ATJ pathways could provide additional demand for low-CI
ethanol for conversion to SAF. A critical step to significantly reduce the CI of ethanol is carbon capture technology, which we
are deploying at multiple locations. SAF is a drop-in fuel, chemically identical to petroleum-based jet fuel and can be blended
into the fuel supply at varying levels. There is an increasing focus on using this fuel to reduce the carbon footprint of air
travel. SAF can be produced from vegetable and waste oil feedstocks, such as our renewable corn oil.
As part of our carbon reduction strategy, we successfully commenced CCS operations at our three Nebraska
biorefineries, which are connected to the Trailblazer CO2 Pipeline. In addition we have committed our four Iowa and
Minnesota facilities to Summit Carbon Solutions, which publicly projects operations commencing in 2028. CCS will lower
GHG emissions through the capture of biogenic carbon dioxide at each of these biorefineries, significantly lowering their CI,
in some cases by more than half. We financed the build and installation of carbon capture equipment at our three Nebraska
plants with Tallgrass and expect to begin repayment during the first quarter of 2026. There are very few ethanol production
facilities with carbon capture in place today, and we are among the first to produce lower-CI ethanol at scale. In addition, we
are exploring alternative options for biogenic carbon dioxide utilization where pipeline transport or direct injection may not
be feasible. Reducing the CI of our ethanol through CCS operations, improving efficiency at our ethanol plants and
purchasing RECs is allowing us to benefit from state, federal and foreign clean fuel programs, including LCFS programs at
the state level and federal tax credits under the IRA, including the Section 45Z Clean Fuel Production Credit, and could
6
position our low-carbon ethanol as a potential feedstock for ATJ pathways to produce SAF, other low carbon fuels and export
markets.
We believe that global demand for protein will continue to rise, requiring larger amounts of high protein feed for pets,
livestock and aquaculture. While faced with growing competition from expanded U.S. soy crushing capacity, we aim to
utilize our protein capabilities to diversify our product offering and optimize our client base.
We began producing Ultra-High Protein using FQT's MSC™ technology in 2020 and have deployed this technology
across four of our biorefinery locations to help meet growing demand for protein feed ingredients and low-carbon renewable
corn oil to use as a feedstock for producing advanced biofuels such as renewable diesel, biodiesel and SAF, as the MSC™
technology enhances renewable corn oil yields. The biorefineries producing Ultra-High Protein, a feed ingredient with
protein concentrations of 50% or greater and yeast concentrations of 25%, have also increased renewable corn oil yields.
In September 2022, we broke ground at our biorefinery in Shenandoah, Iowa, as the first location to deploy FQT's
CST™ at commercial scale, and during 2024 the company successfully commissioned the CST™ equipment in the
Shenandoah facility. FQT’s CST™ allows for the production of both food and industrial grade dextrose at a dry mill ethanol
plant to target applications in food production, in addition to serving as a feedstock for renewable chemicals and synthetic
biology. The facility has a rated capacity of 60 million pounds of product per year. The facility has been idled since the first
quarter of 2025 as the company focuses on optimizing its product mix to maximize current returns. The decision to
temporarily pause operations presents an opportunity to make some related infrastructure improvements, which would
require additional investment.
In July 2023, we announced a technology collaboration with Equilon Enterprises LLC, which allows us to use FQT’s
precision separation and processing technology with Shell Fiber Conversion Technology. The two technologies combine
fermentation, mechanical separation and processing, and fiber conversion into one platform. This has the potential to liberate
nearly all of the remaining distillers corn oil currently bound in the fiber fraction of the corn kernel, generate cellulosic sugars
for production of low-carbon ethanol, and enhance and expand available high protein to produce high-quality ingredients for
global pet, livestock and aquaculture diets. The large-scale demonstration facility is operational and technology and product
development has continued to advance through 2025.
Competitive Strengths
We are focused on managing commodity price risks, improving operational and transportation efficiencies and
optimizing market opportunities to create an efficient platform with diversified income streams. Our competitive strengths
include:
Disciplined Risk Management. Risk management is a core competency and we use a variety of sophisticated risk
management tools and hedging strategies to maintain a disciplined approach. Our internally developed operating margin
management system allows us to monitor commodity price risk exposure in the spot market and on the forward curve at each
of our operations and helps us to lock in favorable margins, when available, or if appropriate, temporarily reduce production
during periods of compressed margins.
Technology Integration. Over our history, we have incorporated new technologies like renewable corn oil extraction and
Selective Milling Technology™ into our manufacturing processes that have enabled us to run more efficiently and improve
our yields and financial results. Through our ownership of FQT and other partnerships, we are currently reviewing a number
of initiatives to further improve operational efficiencies that we believe will lead to improved margins.
FQT provides additional intellectual property rights, including those aimed at developing and implementing proven,
value-added agriculture, food and industrial biotechnology systems, CST™ and MSC™, as well as engineering expertise for
designing ethanol facilities with lower energy use, operational expenses and carbon intensity. We continue to evaluate
additional technological opportunities to expand our capabilities and product offerings in the coming years.
Proven Leadership Team. Our senior leadership team has specific expertise across all of our businesses, including plant
operations and management, commodity markets and risk management, ingredient nutrition, marketing and innovation,
regulatory, legal, policy, and ethanol marketing and distribution. Our leadership team’s level of operational and financial
expertise is essential to successfully executing our business strategies.
Operational Excellence. Our facilities are operated by skilled and experienced personnel who are encouraged to
7
collaborate and share knowledge and expertise across business segments and locations. We remain committed to driving
continuous operational improvements, leveraging advanced systems that provide real-time production data to monitor
production activity and optimize performance.
Risk Management and Hedging Activities
Our margins are highly dependent on commodity prices, particularly for ethanol, corn, distillers grains, Ultra-High
Protein, renewable corn oil and natural gas. Since market price fluctuations among these commodities are not always
correlated, ethanol production has been and may continue to be unprofitable at times. From time to time, we use a variety of
risk management tools and hedging strategies to monitor real-time operating price risk exposure at each of our operations in
an effort to obtain favorable margins, when available.
As market conditions warrant, we use forward contracts to sell a portion of our ethanol, distillers grains, Ultra-High
Protein and renewable corn oil production or buy some of the corn, natural gas, or ethanol we need to partially offset
commodity price volatility. We also engage in other hedging transactions involving exchange-traded futures contracts for
corn, natural gas, ethanol, soybeans, soybean meal and soybean oil. The financial impact of these activities depends on the
price of the commodities involved and our ability to physically receive or deliver those commodities.
Hedging arrangements expose us to risk of financial loss when the counterparty defaults on its contract or, in the case of
exchange-traded contracts, when the expected differential between the price of the underlying commodity and physical
commodity changes. Hedging activities can result in losses when a position is purchased in a declining market or sold in a
rising market. Hedging losses may be offset by a decreased cash price for corn and natural gas and an increased cash price for
ethanol, distillers grains, Ultra-High Protein and renewable corn oil. Depending on the circumstance, we vary the amount of
hedging or other risk mitigation strategies we undertake and sometimes choose not to engage in hedging or risk management
transactions at all.
Recent Developments
The following is a summary of our significant recent developments. Additional information about these items can be
found elsewhere in this report or in previous reports filed with the SEC.
CCS Commencing Operations
CCS equipment at our three Nebraska plants began operations during the fourth quarter of 2025, and is delivering
biogenic carbon dioxide to the Tallgrass Trailblazer pipeline for permanent sequestration. Successful sequestration has
allowed the company to further reduce its CI, triggering an increase in the amount of income tax benefit recognizable from
Section 45Z production tax credits in the current period and in future periods.
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. Six of our eight operating ethanol plants have generated production tax credits under Section
45Z in 2025 and all eight are projected to generate these credits in 2026. The company has purchased RECs during the year
ended December 31, 2025 to lower CI scores at certain plants. Based on production and CI scores for the year ended
December 31, 2025, the company recorded income tax benefit of $54.2 million, net of a valuation allowance, related to
Section 45Z production tax credits at the six qualifying plants.
Tax Credit Purchase Agreement
On September 16, 2025, the company entered into an agreement, pursuant to which the company agreed to supply
production tax credits available under Section 45Z to a buyer from the production of the company's ethanol at its three
Nebraska facilities between January 1, 2025 and December 31, 2025. On December 10, 2025, the agreement was amended to
add Section 45Z production tax credits produced at three more of the company's facilities. All credits generated during the
year ended December 31, 2025, were sold in accordance with these agreements.
Convertible Debt Exchange
On October 27, 2025, the company executed separate, privately negotiated exchange agreements with certain of the
holders of its existing 2.25% Convertible Senior Notes due 2027 (the “2027 Notes”) to exchange (the “exchange
transactions”) $170 million aggregate principal amount of the 2027 Notes for $170 million of newly issued 5.25%
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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”). $200 million in aggregate principal amount of the 2030 Notes is now outstanding, and $60
million in aggregate principal amount of the 2027 Notes remains outstanding with existing terms unchanged.
The company used approximately $30 million of the net proceeds from the subscription transactions to repurchase
approximately 2.9 million shares of its common stock from certain holders participating in 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 notes will be general senior, 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.
Green Plains Obion LLC Disposition
On August 27, 2025, the company announced that its wholly owned subsidiary, Green Plains Obion LLC, entered into an
asset purchase agreement for the sale of the ethanol plant located in Rives, Tennessee, to POET Biorefining - Obion, LLC.
On September 25, 2025, the company closed on the sale and received proceeds of $170 million plus related working capital
(the “Obion Transaction”). A gain of $35.8 million was recorded in gain on sale of assets, net on the consolidated statements
of operations. The proceeds from the sale were used to repay the outstanding balance of the Junior Notes due 2026 and to
supplement corporate liquidity.
Junior Notes and Warrant Amendments
On May 7, 2025, the company amended its $125 million of Junior Notes to extend the maturity date to May 15, 2026,
with an amendment fee of 2.0% added to the principal balance of the Junior Notes, payable at the maturity date. Further, the
strike price of the warrants was revised from $22.00 to $0.01 and the maturity date extended from April 28, 2026 to
December 31, 2029.
On August 10, 2025, the company amended and restated the indenture covering the Junior Notes with BlackRock to
extend the maturity date to September 15, 2026, with an amendment fee of 2.5% added to the principal balance of the Junior
Notes, payable at the maturity date. The interest rate increased by 0.5% after the amendment, and by an additional 0.5% each
quarter on each scheduled interest payment date. The amendment added certain financial covenant requirements, including
restrictions on additional debt and certain transfer of assets. Also as part of the amendment, the company executed a
subscription agreement with certain funds and accounts under management by BlackRock pursuant to which the company
agreed to issue, and certain funds and accounts under management by BlackRock purchased, 3,250,000 stock warrants at a
strike price of $0.01 per share with a ten year exercise period. The amendment also included the right for such funds and
accounts to exchange up to 750,000 warrants for a pro rata share of $6 million of outstanding principal of Junior Notes. The
subscription agreement obligated the company to register for resale the shares of common stock underlying warrants issued
to BlackRock. On September 25, 2025, proceeds from the Obion Transaction were used to fully retire the Junior Notes. All
warrants issued to BlackRock were exercised during the year ended December 31, 2025.
GP Turnkey Tharaldson Disposition
On June 30, 2025, the company sold its 50% investment in GP Turnkey Tharaldson for $24.3 million. A pretax loss of
$26.9 million was recorded during year ended December 31, 2025.
Ancora Credit Facility and Warrants
On May 7, 2025, the company entered into a secured $30 million revolving credit facility with Ancora Alternatives LLC,
that matured on July 30, 2025. The facility bore interest at 10% on borrowings and had a 0.5% fee on the unused balance.
Interest and fees were due on the 5th of each month. Also executed as part of the credit facility, the company issued
1,504,140 stock warrants at a strike price of $0.01 per share. The warrants had a ten year exercise period. On August 29,
2025, the Ancora warrants were fully exercised.
Ethanol Marketing Agreement with Eco-Energy, LLC
On April 16, 2025, the company entered into an ethanol marketing agreement with Eco-Energy, LLC. The marketing
agreement is for a term of five years, with certain early termination rights, and requires the company to sell exclusively to
Eco-Energy LLC, and for Eco-Energy LLC to purchase from the company all fuel grade ethanol, or other ethanol
specifications as agreed to for a predetermined market-based marketing fee that may be adjusted based on gallons shipped.
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Eco-Energy, LLC has also agreed to handle certain back office duties related to the ethanol marketing and logistics across the
company's platform, providing end-to-end support to optimize value, expand market access and improve supply chain
efficiency. On April 14, 2025, a conforming amendment was entered into on the $350 million revolver to accommodate
concentration risk with Eco-Energy, LLC.
Cooperation Agreement
On April 11, 2025, the company entered into a Cooperation Agreement with Ancora Holdings Group, LLC, a long-term
shareholder, which outlines certain compositional changes to the Board, and provides for a standstill, voting commitment and
other customary provisions.
The execution of the Cooperation agreement resulted in the appointment of three individuals as independent members to
the Board on April 14, 2025, Steve Furcich, Carl Grassi, and Patrick Sweeney. These individuals possess additive experience
in key areas such as the agriculture and commodities sector, capital allocation, finance, long-term planning, and strategic
reviews and transactions. From April 14, 2025, through the Annual Meeting, the appointments resulted in an expansion of the
Board to ten members. The Board was reduced to eight members due to Ejnar A. Knudsen III and Alain Treuer not standing
for re-election at the 2025 Annual Meeting.
Leadership Transition
On February 28, 2025, the company announced the departure of Todd Becker as President and Chief Executive Officer
and member of the Board, effective March 1, 2025.
Effective March 1, 2025, the Board appointed Michelle Mapes, Chief Legal & Administration Officer, as Interim
Principal Executive Officer, and also appointed an executive committee comprised of Ms. Mapes, Jamie Herbert, Chief
Human Resource Officer, Chris Osowski, Executive Vice President, Operations and Technology, and Imre Havasi, Senior
Vice President – Head of Trading and Commercial Operations, which led the company until Mr. Becker’s successor was
appointed. As part of the company’s corporate reorganization, Michelle Mapes' position as Chief Legal and Administration
Officer and Corporate Secretary was contractually agreed to be eliminated at December 31, 2025 pursuant to an amendment
to her employment contract dated February 27, 2025. Both Grant Kadavy's position of EVP - Commercial Operations and
Leslie van der Meulen's position of EVP - Product Marketing and Innovation were eliminated, effective February 6, 2025.
On August 19, 2025, the Board of Directors of the company appointed Chris Osowski as Chief Executive Officer and
member of the Board of Directors of the company, effective immediately. Mr. Osowski served as a member of the company’s
Executive Committee since March 2025 and served as Executive Vice President, Operations and Technology since January
2022. Also, in connection with Mr. Osowski’s appointment, the company promoted Trent Collins to serve as Senior Vice
President of Operations.
On January 5, 2026, the Board of Directors of the company appointed Ann Reis to serve as Chief Financial Officer of the
company effective January 6, 2026, who succeeds Phil Boggs who departed the company on January 5, 2026.
On January 12, 2026, the company announced the appointment of Ryan Loneman to serve as the General Counsel and
Corporate Secretary of the company effective January 26, 2026.
Restructuring Costs
As part of the strategic review process, in early 2025, the company launched a corporate reorganization and cost
reduction initiative that has significantly reduced selling, general and administrative expenses on an ongoing basis. As part of
this initiative, the company identified approximately $50 million of financial improvement annually, inclusive of savings
from idling the Fairmont, Minnesota facility, transitioning to a third party ethanol marketer, and realigning corporate and
trade group selling, general and administrative functions to reflect current strategic priorities. As a result of the
reorganization, the company recorded one-time restructuring costs of $24.3 million during the year ended December 31,
2025, which includes severance related to the departure of its former CEO.
Strategic Review
On August 27, 2025, the company announced the conclusion of its strategic review process, which began in February
2024. Following a comprehensive evaluation, the Board of Directors considered a range of alternatives and determined that
the company is best positioned to deliver shareholder value by executing its current strategy under existing leadership. This
outcome of the review has provided a roadmap for continued operational execution and capital discipline.
Idling of Clean Sugar Technology facility in Shenandoah, Iowa
During the first quarter, the company idled its operations at the CST™ facility in Shenandoah, Iowa, as the company
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focuses on optimizing its product mix to maximize current returns. The decision to temporarily pause operations presents an
opportunity to make some related infrastructure improvements, which would require additional investment.
Idling of Fairmont, Minnesota Plant
In January 2025, the company idled its 119 million gallon ethanol plant in Fairmont, Minnesota as a result of persistent
margin pressures, and the majority of the staff was terminated. The company is continuing to monitor the potential of 45Z
production tax credit monetization, which would be further enhanced by carbon capture and sequestration. This would
fundamentally reshape the economics of the facility.
Operating Segments
Ethanol Production Segment
Industry Overview. Ethanol, also known as ethyl alcohol or grain alcohol, is a colorless liquid produced by fermenting
carbohydrates found in a number of different types of grains, such as corn, wheat and sorghum, and other cellulosic matter
found in plants. Most of the ethanol produced in the United States is made from corn, which can be handled efficiently and is
in greater supply than other grains. Corn contains large quantities of carbohydrates that convert into glucose more easily than
most other kinds of biomass. According to the USDA, on average, a 56 pound bushel of corn produces approximately 2.9
gallons of ethanol, 17 pounds of dried distillers grains and 0.6 pounds of corn oil. Outside of the United States, sugarcane is
the primary feedstock used to produce ethanol.
Ethanol is a significant component of the biofuels industry, which includes all transportation fuels derived from
renewable biological materials. Ethanol is an excellent oxygenate and source of octane. When added to petroleum-based
transportation fuels, oxygenates reduce vehicle emissions. Ethanol is the most economical oxygenate and source of octane
available on the market and its production costs are competitive with gasoline.
Ethanol Plants. We own nine ethanol plants, located in five states, that produce ethanol, distillers grains, Ultra-High
Protein and renewable corn oil.
The capacity disclosed below has been adjusted in the current period to represent the plants proven abilities to produce
beyond their nameplate capacity. The company's historical capacity disclosures were based on plant nameplate capacity. The
increased capacity is the result of a projection of annual capacity based on actual production levels achieved, and was not due
to significant plant expansion or enhancement during the period.
Plant Location
Stated Production
Capacity (mmgy)
Central City, Nebraska (1) (2)
120
Fairmont, Minnesota (3) (4)
120
Madison, Illinois
100
Mount Vernon, Indiana (1)
110
Otter Tail, Minnesota (3)
70
Shenandoah, Iowa (1) (3)
80
Superior, Iowa (3)
70
Wood River, Nebraska (1) (2)
120
York, Nebraska (2)
60
Total
850
(1)
Produces Ultra-High Protein.
(2)
Connected to Tallgrass Trailblazer Pipeline.
(3)
Committed to Summit Carbon Solutions Pipeline.
(4)
Plant idled in January 2025.
Our business is directly affected by the supply and demand for ethanol and other fuels in the markets served by our
assets. Miles driven typically increase during the spring and summer months related to vacation travel, followed closely by
the fall season due to holiday travel.
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Corn Feedstock and Ethanol Production. Our plants use corn as feedstock in a dry mill ethanol production process. Each
of our plants requires on average approximately 32 million bushels of corn annually, depending on its production capacity.
The price and availability of corn are subject to significant fluctuations driven by a number of factors that affect commodity
prices in general, including crop conditions, weather, governmental programs, freight costs and global demand. Ethanol
producers are generally unable to pass increased corn costs to customers.
Our corn supply is obtained primarily from local markets. We use cash and forward purchase contracts with grain
producers and elevators to buy corn. We maintain direct relationships with local farmers, grain elevators and cooperatives,
which serve as our primary sources of grain feedstock for all ten of our ethanol plants. This allows us to purchase much of the
corn we need directly from farmers throughout the year. Each of our plants is also situated on rail lines or has other logistical
solutions to access corn supplies from other regions of the country should local supplies become insufficient.
Corn is received at the plant by truck or rail then weighed and unloaded into a receiving building. Grain storage facilities
are used to inventory grain that is passed through a scalper to remove rocks and debris prior to processing. The corn is then
transported to a hammer mill where it is ground into flour and conveyed into a slurry tank for enzymatic processing. Water,
heat and enzymes are added to convert the complex starch molecules into simpler carbohydrates. The slurry is heated to
reduce the potential of microbial contamination and pumped into a liquefaction tank where additional enzymes are added.
Next, the grain slurry is pumped into fermenters, where yeast, enzymes, and nutrients are added and the fermentation process
is started. A beer column, within the distillation system, separates the alcohol from the spent grain mash. The alcohol is
dehydrated to 200-proof alcohol and pumped into a holding tank and blended with approximately 2% denaturant as it is
pumped into finished product storage tanks.
Distillers Grains. The spent grain mash is pumped from the beer column into a decanter-type centrifuge for dewatering.
The water, or thin stillage, is pumped from the centrifuge into an evaporator, where it is concentrated into a thick syrup. The
solids, or wet cake, that exit the centrifuge are conveyed to the dryer system and dried at varying temperatures to produce
distillers grains. Syrup is reapplied to the wet cake prior to drying to provide additional nutrients. Distillers grains, the
principal co-product of the ethanol production process, are used as mid-protein, high-energy animal feed and marketed to the
dairy, beef, swine and poultry industries.
We can produce three forms of distillers grains, depending on the number of times the solids are passed through the dryer
system:
•
wet distillers grains, which contain approximately 65% to 70% moisture, have a shelf life of approximately three
days and is therefore sold to dairies or feedlots within the immediate vicinity of our plants;
•
modified wet distillers grains, which is dried further to approximately 50% to 55% moisture, have a shelf life of
approximately three weeks and are marketed to regional dairies and feedlots; and
•
dried distillers grains, which have been dried more extensively to approximately 10% to 12% moisture, have an
almost indefinite shelf life and may be stored, sold and shipped to any market.
Ultra-High Protein. Ultra-High Protein is fermented corn protein produced by further processing of the spent grain mash
from the beer column. The spent grain is processed using FQT’s MSC™ technology, which contains a series of screening
equipment to remove fiber from the spent grain which is sent to the distillers grain dryer. The remaining product is washed
and clarified into a wet protein stream which is dried in a ring dryer to produce Ultra-High Protein meal with protein
concentrations of approximately 50%. Our specialty feed ingredient, Sequence™ has protein concentrations of approximately
60%.
Renewable Corn Oil. Renewable corn oil systems extract non-edible renewable corn oil from the thin stillage
evaporation process immediately before the production of distillers grains. Renewable corn oil is produced by processing the
syrup through a decanter-style, or disk-stack, centrifuge. The centrifuges separate the relatively light renewable corn oil from
the heavier components of the syrup. Across our entire platform, we extract on average approximately 1.0 pound of
renewable corn oil per bushel of corn used to produce ethanol. Industrial uses for renewable corn oil are primarily as a
feedstock for renewable diesel and biodiesel. Additionally, it is also used as a livestock feed additive.
Natural Gas. Depending on production parameters, our ethanol plants use on average approximately 27,000 BTUs of
natural gas per gallon of production. We have service agreements to acquire the natural gas we need and transport the gas
through pipelines to our plants.
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Electricity. Our plants require on average approximately 0.9 kilowatt hours of electricity per gallon of production. Local
utilities supply the necessary electricity to all of our ethanol plants.
Water. While some of our plants satisfy a majority of their water requirements from wells located on their respective
properties, each plant also obtains drinkable water from local municipal water sources. Each facility either uses city water or
operates a filtration system to purify the well water that is used for its operations. Local municipalities supply all of the
necessary water for our plants that do not have onsite wells. Most of the water used in an ethanol plant is recycled in the
production process.
Transportation, Delivery and Terminal Services. Most of our ethanol plants are situated near major highways or rail lines
to ensure efficient product movement. Deliveries within 150 miles of our plants and the fuel terminal facility are generally
transported by truck. Deliveries to distant markets are shipped using major U.S. rail carriers that can switch cars to other
major railroads, allowing our plants to ship product throughout the United States and to international export terminals. As of
December 31, 2025, the leased railcar fleet consisted of approximately 1,944 ethanol railcars with an aggregate capacity of
57.7 mmg, and 860 hopper and tank cars to transport other co-products and raw materials. We expect the railcar volumetric
capacity to fluctuate over the normal course of business as the existing railcar leases expire and we enter into or acquire new
railcar leases. The company owns and operates one fuel terminal with a storage capacity of approximately 180 thousand
gallons and throughput capacity of approximately 40 mmgy.
Agribusiness and Energy Services Segment
Our agribusiness and energy services segment includes grain storage at our ethanol plants of approximately 12.0 million
bushels, detailed in the following table:
Facility Location
On-Site Grain Storage Capacity
(thousands of bushels)
Central City, Nebraska
1,400
Fairmont, Minnesota (1)
1,611
Madison, Illinois
1,015
Mount Vernon, Indiana
1,034
Otter Tail, Minnesota
628
Shenandoah, Iowa
886
Superior, Iowa
1,770
Wood River, Nebraska
3,293
York, Nebraska
363
Total
12,000
(1)
Plant idled in January 2025.
We buy bulk grain, primarily corn, from area producers, and provide grain drying and storage services to those
producers. The grain is used as feedstock for our ethanol plants. Bulk grain commodities are traded on commodity exchanges
and inventory values are affected by changes in these markets. To mitigate risks related to market fluctuations from purchase
and sale commitments of grain, as well as grain held in inventory, we enter into exchange-traded futures and options contracts
that function as economic and designated accounting hedges at times.
Seasonality is present within our agribusiness operations. The fall harvest period typically results in higher handling
margins and stronger financial results during the fourth quarter of each year.
Through Green Plains Trade, we historically provided marketing services for our nine ethanol plants for all of the co-
products produced at these locations as well as marketed ethanol for a third party, which ceased in April of 2025, and
continue to provide marketing services to our ethanol plants for natural gas procurement. Green Plains Trade ceased
marketing ethanol produced by the plants in April of 2025, but continues to market all other co-products. Eco-Energy, LLC
now markets the ethanol produced by the plants.
Our ethanol is marketed by Eco-Energy LLC to local, regional, national and international customers. We also purchase
ethanol from independent producers for pricing arbitrage from time to time. Our ethanol is sold to various markets under
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sales agreements with integrated energy companies; retailers, traders and resellers in the United States and buyers for export
to Canada. Under these agreements, ethanol is priced under both fixed and indexed pricing arrangements.
We market distillers grains to local, domestic and international markets through Green Plains Trade. The bulk of our
demand is delivered to geographic regions that do not have significant local corn, distillers grains or high protein ingredients
production. We sell to international markets indirectly through exporters. Access to diversified markets allows us to sell
product to customers offering the highest net price.
Our renewable corn oil is sold primarily to renewable diesel and biodiesel plants and, to a lesser extent, feedlot and
poultry markets. We transport our renewable corn oil by truck to locations in a close proximity to our ethanol plants primarily
in the southeastern and midwestern regions of the United States. We also transport renewable corn oil by rail to national
markets as well as to exporters for shipment on vessels to international markets.
We provide marketing services of natural gas to our ethanol plants including the procurement of both the pipeline
capacity and natural gas. We also enhance the value by aggregating volumes at various storage facilities which can be sold to
either the plants or various intermediary markets and end markets.
For more information about our segments, refer to Item 7. - Management’s Discussion and Analysis of Financial
Condition and Results of Operations in this report.
Our Competition
Domestic Ethanol Competitors
We are one of the largest consolidated owners of ethanol plants in the United States. We compete with other domestic
ethanol producers in a highly fragmented industry. Our competitors also include plants owned by farmers, cooperatives, oil
refiners and retail fuel operators. These competitors may continue to operate their plants even when market conditions are not
favorable due to the benefits realized from their other operations and lower cost structures.
As of December 31, 2025, the top four producers accounted for approximately 39% of the domestic production capacity
with production capacities ranging from 850 mmgy to 3,146 mmgy. Demand for corn from ethanol plants and other corn
consumers exists in all areas and regions in which we operate. According to the Renewable Fuels Association, there were 114
operational plants in Illinois, Indiana, Iowa, Minnesota and Nebraska, which are the states where we have production
facilities as of December 31, 2025. The largest concentration of operational plants is located in Iowa, Nebraska and Illinois,
where approximately 50% of all operational production capacity is located.
Foreign Ethanol Competitors
We also compete globally with production from other countries. Brazil is the second largest ethanol producer in the
world after the United States. Brazil primarily produces ethanol made from sugarcane, which may be less expensive to
produce than ethanol made from corn depending on feedstock prices. Under the RFS, certain parties are obligated to meet an
advanced biofuel standard, and Brazilian sugarcane ethanol qualifies as an advanced biofuel. Any significant additional
ethanol production capacity, or reduced demand for gasoline, could create excess supply in world markets, resulting in lower
ethanol prices throughout the world, including the United States.
Other Competition
Alternative fuels, gasoline oxygenates and ethanol production methods are continually under development. Ethanol
production technologies also continue to evolve. We anticipate changes could occur primarily in the area of cellulosic
ethanol, or from biodigesters at landfills or livestock production facilities. Since all of our plants are designed as single-
feedstock facilities, adapting our plants for a different feedstock or process system would require additional capital
investments and retooling which could be cost prohibitive, and would require new RFS pathways to be approved by the EPA.
Our distillers grains and Ultra-High Protein feed ingredients compete against other feed ingredients including soybean meal,
canola meal, ground corn, corn gluten meal and distillers grains from other ethanol producers domestically and abroad. Our
renewable corn oil competes against vegetable oils such as soybean oil, canola oil, and to some extent palm oil, as well as
waste feedstocks including used cooking oil, animal fats and tallow.
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Regulatory Matters
Government Ethanol Programs and Policies
We are sensitive to domestic and foreign governmental policies that impact ethanol, feedstocks for renewable fuels and
decarbonization, which in turn may impact the volume of ethanol and other ingredients we produce. Legislation and
regulatory rule making at the federal, state and international level can impact us across all business segments. Refer to Item 7.
- Management’s Discussion and Analysis of Financial Condition and Results of Operations in this report for a detailed
discussion of these topics.
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
clean fuel programs, tariffs, duties, subsidies, import and export restrictions and outright embargos.
On June 13, 2025, the FERC issued an order approving a Stipulation and Consent Agreement ("Consent Agreement")
between the Office of Enforcement (“OE”) and the company. The Consent Agreement resolved the OE’s investigation into
trading activity conducted by the company which occurred during 2023. As part of the Consent Agreement, the company
agreed to pay a civil penalty of $0.9 million, pay $23 thousand in restitution and interest, implement enhancements to its
compliance program and be subject to certain trading restrictions.
Human Capital Resources
Attracting, retaining and developing talented employees is essential to our success. We accomplish this, in part, by our
competitive compensation practices, training initiatives, and growth opportunities within the company. On December 31,
2025, we had 642 full-time, part-time, temporary and seasonal employees, including 71 employees at our corporate office in
Omaha, Nebraska.
Workforce Health and Safety
We prioritize workplace safety through a comprehensive safety program that continuously assesses and enhances our
protocols to maintain a safe and secure environment for our employees.
Compensation and Benefits
As part of our compensation philosophy, we believe that we must offer and maintain market competitive compensation
and benefit programs for our employees in order to attract and retain superior talent. In addition to competitive base wages,
additional programs include the 2019 Equity Incentive Plan, a company-matched 401(k) Plan, healthcare and insurance
benefits, flexible spending accounts, paid time off, bonding leave, and employee assistance programs.
Available Information
Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to
those reports are available on our website at www.gpreinc.com shortly after we file or furnish the information with the SEC.
You can also find the charters of our audit, compensation and nominating committees, as well as our code of ethics in the
corporate governance section of our website. The information found on our website is not part of this or any other report we
file with or furnish to the SEC. Alternatively, investors may visit the SEC website at www.sec.gov to access our reports, proxy
and information statements filed with the SEC.
Item 1A. Risk Factors.
Our operations are subject to risks and uncertainties that could cause actual results to differ materially from those
discussed in this Form 10-K and could have a material adverse impact on our financial results. The risks described below are
not the only risks facing us. Additional risks and uncertainties not currently known or currently viewed to be immaterial may
also materially and adversely affect business, financial condition or results of operations. These risks can be impacted by
15
factors beyond management's control. The following risk factors and the forward-looking statements contained elsewhere in
this Form 10-K should be read carefully when evaluating us.
Risks Related to our Business and Industry
Risks Related to Carbon Capture and Sequestration Projects, and 45Z Production Tax Credits, Including Operational,
Regulatory, and Market Uncertainties
We have seven facilities committed to carbon capture and sequestration (CCS) projects, including CCS projects now
operating at three Nebraska locations. While the Summit projects have not commenced construction of CCS, with respect to
the three Nebraska CCS projects, they could face a range of risks including but not limited to facility operational issues, that
could delay, reduce, or suspend carbon capture operations and/or reduce tax benefits. Moreover, all eight of our operating
ethanol plants likely will qualify for 45Z production tax credits under IRC Section 45Z with six positioned to claim credits in
2025 and all eight in 2026, based on current laws and regulations. After the 45Z tax credits have sunsetted, which is currently
scheduled for 2029, the facilities with carbon capture that are owned by the company will be able to claim the 45Q tax
credits, which are available for twelve years after the date of capture equipment construction completion.
While we strive to comply with all federal tax incentive qualification requirements for all of our carbon initiatives, i.e.
those with CCS and those facilities that qualify for federal tax incentives without CCS—including prevailing wage and
apprenticeship rules—we cannot provide assurance that we will be in compliance at all times or will not incur material costs
or liabilities as a result. Moreover, even if operational and technical goals are achieved, the CI reductions we anticipate may
not fully materialize. Regulatory CI modeling frameworks may change in ways that are outside our control and could reduce
or eliminate the expected benefits of our carbon initiatives.
Federal policies, such as those enacted under the IRA, may also change. Future modifications could adversely impact
corn-based ethanol from accessing key tax incentives, or otherwise reduce potential benefits. In addition, delays in issuing or
finalizing regulations, regulations not consistent with industry expectation or the rescission of clean energy or carbon capture
tax credits at the federal, state, or international levels, could negatively affect our carbon initiatives.
We are also exposed to risks related to our ability to monetize Section 45Z production tax credits and voluntary carbon
credits at values we currently expect, or at all. Uncertainty in tax credit markets, changes in demand, or regulatory shifts
could significantly impact the economic returns from our carbon initiatives. Similarly, developments in the voluntary carbon
credit markets, including fluctuating buyer interest, changes in verification standards, or reduced market confidence, could
undermine the value of our credits or make monetization infeasible.
Lastly, while much of our current CCS risk relates to facilities under our control, additional risks exist in connection with
factors outside of our control such as the supporting infrastructure, including the carbon pipeline and injection wells. Delays
in permitting, construction, or operational issues with these components could impair our ability to capture or permanently
sequester CO₂, with limited ability to insure certain risks, and thereby limit, reduce, or nullify the benefits of the CCS facility-
level investments and adversely affect our business, tax benefits and/or profitability.
Our margins are dependent on managing the spread between the price of corn, natural gas, ethanol, distillers grains, Ultra-
High Protein and renewable corn oil.
Our operating results are highly sensitive to the spread between the corn and natural gas we purchase, and the ethanol,
distillers grains, Ultra-High Protein and renewable corn oil we sell. Price and supply are subject to various market forces,
such as weather, domestic and global supply and demand, global political or economic issues, including but not limited to
global conflicts, shortages, export prices, crude oil prices, currency valuations and government policies in the United States
and around the world, over which we have no control. Price volatility of these commodities may cause our operating results
to fluctuate substantially. No assurance can be given that we will purchase corn and natural gas or sell ethanol, distillers
grains, Ultra-High Protein and renewable corn oil at or near prices which would provide us with positive margins.
Consequently, our results of operations and financial position may be adversely affected by increases in corn or natural gas
prices or decreases in ethanol, distillers grains, Ultra-High Protein and renewable corn oil prices. We have made significant
investments in our biorefinery platform to produce Ultra-High Protein, and our financial results are impacted by our ability to
operate these new systems consistently and to sell the products into new markets at a premium to distillers grains. Rapid
expansion of soybean crushing capacity to meet the soybean oil demands of the growing renewable diesel and biomass-based
diesel industry could result in an oversupply of soybean meal, which could depress prices for various protein feed
ingredients, and negatively impact our anticipated financial returns.
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We continuously monitor the margins at our ethanol plants using a variety of risk management tools and hedging
strategies when appropriate. Should our combined revenue from ethanol, distillers grains, Ultra-High Protein and renewable
corn oil fall below our cost of production, we could decide to slow or suspend production at some or all of our ethanol plants,
which could also adversely affect our results of operations and financial position.
The products we buy and sell are subject to price volatility and uncertainty.
Our operating results are highly sensitive to commodity prices.
Corn. We are generally unable to pass increased corn costs to our customers since ethanol competes with other fuels. We
continue to see considerable volatility in corn prices. Ethanol plants, livestock industries and other corn-consuming
enterprises put significant price pressure on local corn markets. In addition, local corn supplies and prices could be adversely
affected by, but not limited to: prices for alternative crops, increasing pricing for seed corn, fertilizers, crop protection
products and other input costs; changes in government policies, including crop insurance, conservation programs, regulation
of farmland, and other regulations; shifts in global supply and demand; global political or economic issues, including but not
limited to global conflicts and global or regional growing conditions, such as plant disease, pests or adverse weather,
including drought.
Ethanol. Our revenues are dependent on market prices for ethanol which can be volatile as a result of a number of
factors, including but not limited to: the price and availability of competing fuels and oxygenates for fuels; the domestic and
global supply and demand for ethanol, gasoline and corn; the price of gasoline, crude oil and corn; global political or
economic issues, including global conflicts and domestic and foreign government policies that impact the supply, demand
and pricing of corn, crude oil, gasoline, ethanol and other liquid fuels.
Ethanol is marketed as a fuel additive that reduces vehicle emissions, an economical source of octane and, to a lesser
extent, as a gasoline substitute through higher blends such as E15 and E85. Consequently, gasoline supply and demand can
affect the price of ethanol. Should gasoline prices or demand change significantly, our results of operations could be
materially impacted.
Ethanol imports also affect domestic supply and demand. Imported ethanol is not subject to an import tariff under the
United States-Mexico-Canada Agreement (USMCA), provided it satisfies the agreement’s rules of origin, which are required
for preferential tariff treatment. As of early 2025, denatured ethanol for fuel use imported from Brazil and other countries
subject to Most Favored Nation treatment is generally subject to a 1.9% ad valorem tariff, while undenatured ethanol is
subject to a 2.5% ad valorem tariff. However, a series of executive orders issued in March and April of 2025 have introduced
or proposed significant changes to U.S. trade policy, including a baseline 10% tariff on a broad range of imported goods,
unless replaced by higher country-specific rates. Additionally, on July 15, 2025, The Office of the U.S. Trade Representative
initiated a Section 301 investigation into Brazil’s unfair trading practices. While Brazil’s tariffs on U.S. ethanol have
fluctuated since 2017, they have been set at 18% since January 1, 2024. These developments have created uncertainty around
ethanol import pricing and raised the risk of retaliatory trade measures. We continue to monitor potential adjustments to tariff
levels or exemptions as trade negotiations evolve. Under the RFS, sugarcane ethanol from Brazil can be used as a means for
obligated parties to meet the advanced biofuel standard in addition to state level low-carbon fuel standards. Brazil is also
rapidly expanding corn and corn ethanol production, which can have a lower CI score if it is produced from the second crop
or “Safrinha” crop, which could be imported into the U.S. or displace our exports elsewhere globally.
Distillers Grains. Distillers grains compete with other protein-based animal feed products. Downward pressure on other
commodity prices, such as corn, wheat, soybeans, soybean meal, and other feed ingredients, will generally cause the price of
competing animal feed products to decline, resulting in downward pressure on the price of distillers grains. Occasionally, the
price of distillers grains will lag behind fluctuations in corn or other feedstock prices, lowering our cost recovery percentage.
Additionally, exports of distiller grains could be impacted by the enactment of foreign policy, or expanded production of
soybean meal or distillers grains elsewhere.
Natural Gas. The price and availability of natural gas are subject to volatile market conditions. These market conditions
are often affected by factors beyond our control, such as weather, drilling economics, overall economic conditions and
government regulations. Significant disruptions in natural gas supply could impair our ability to produce ethanol.
Furthermore, increases in natural gas prices or changes in our cost relative to our competitors cannot be passed on to our
customers, which may adversely affect our results of operations and financial position.
Ultra-High Protein. Our Ultra-High Protein has unique nutritional advantages and a higher protein concentration than
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soybean meal and can be included in a variety of feed rations in the pet, dairy, swine, poultry and aquaculture industries. As a
value-added feed ingredient, quality control is imperative. Demand for feed products and pricing pressure from competing
feed products may result in downward pressure on the price of Ultra-High Protein. Reliable production of Ultra-High Protein
from both consistent operations of the biorefinery as well as the MSC™ technology is necessary to produce anticipated
volumes. Changes in our customers' willingness to accept these ingredients, inconsistency in production volumes, quality or
downward pressure on prices could result in adverse impact on our business and profitability.
Renewable Corn Oil. Renewable corn oil is marketed as a low-carbon feedstock for biofuel production including
renewable diesel, biodiesel and currently to a lesser extent, sustainable aviation fuel. The price of renewable corn oil is
largely influenced by demand for these fuels, particularly renewable diesel, as well as broader dynamics within the vegetable
oil and feedstock markets. They are also impacted by margin dynamics within the renewable diesel industry and the relative
pricing and availability of alternative feedstocks, domestic or imported. Expanded demand from the renewable diesel and
biodiesel industry due to RVOs, new tax credits included in the IRA, growing LCFS markets in California, Oregon,
Washington state or Canada as well as customer acceptance for such fuels could impact renewable corn oil demand. Recent
restrictions imposed on imported feedstocks also provide benefits. In general, renewable corn oil prices follow the prices of
heating oil and soybean oil but corn oil trades at a premium for its low CI score. Corn oil prices are well supported as a result
of current incentives and import restrictions. If the soy complex would come under pressure due to oversupply of soybeans,
corn oil prices would also be pressured. Further, if the EPA continues to issue SREs, it could lead to downward pressure on
renewable feedstock prices including corn oil.
We may be affected by or unable to fulfill our strategies.
We continually evaluate the makeup of our portfolio, and we may sell additional assets or businesses or exit particular
markets that are no longer a strategic fit or no longer meet their growth or profitability targets. Depending on the nature of the
assets sold, our profitability may be impacted by lost operating income or cash flows from such businesses. In addition,
divestitures we complete may not yield the targeted improvements in our business and may divert management’s attention
from our day-to-day operations.
We may not achieve the operating yields we project or our technologies may not perform as expected. We may not
achieve product market sales, margins or pricing we project, and our operating cost goals may not be achieved due to a
variety of factors. Our failure to achieve our production, sales and pricing targets, including, but not limited to: construction,
yield, sales, margin, pricing, or financial results associated with our strategies could have an adverse effect on our business,
financial condition or results of operations.
Domestic and foreign government biofuels programs could change and impact the ethanol market.
Domestic and foreign governments have adopted biofuels programs that drive demand for biofuels. In the United States,
the RFS mandates the minimum volume of renewable fuels that must be blended into the transportation fuel supply each year,
which affects the domestic market for ethanol. Similarly, Canada has adopted clean fuel regulations incenting the use of
biofuels, as have other countries.
In the U.S., through 2022, the EPA undertook rulemaking to set the RVO for the following year, though at times months
or years would pass without a finalized RVO. Further, the EPA has the authority to waive the requirements, in whole or in
part, if there is inadequate domestic renewable fuel supply or the requirement severely harms the economy or the
environment. After 2022, volumes are determined by the EPA in coordination with the Secretaries of Energy and Agriculture,
taking into account such factors as impact on environment, energy security, future rates of production, cost to consumers,
infrastructure, and other factors such as impact on commodity prices, job creation, rural economic development or food
prices. The EPA also has the authority to set volumes for multiple years at a time, rather than annually as required prior to
2022. In June 2023, the EPA finalized a multi-year RVO for 2023, 2024 and 2025. In June 2025, the EPA proposed a multi-
year RVO for 2026 and 2027. In September 2025, the EPA issued a supplemental proposal to reallocate volumes waived
under SREs.
Volumes can also be impacted as small refineries can petition the EPA for an SRE which, if approved, waives their
portion of the annual RVO requirements. The EPA, through consultation with the DOE and the USDA, can grant them a full
or partial waiver, or deny it outright within 90 days of submittal. Elimination of a refinery's obligation effectively lowers the
amount of renewable fuels required to be blended, and by extension the amount 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 August and November 2025, the EPA granted or partially granted 187
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SREs, largely clearing the backlog from 2016-2024.
The D.C. Circuit Court of Appeals ruled that the EPA overstepped its authority in extending the one pound Reid Vapor
Pressure waiver for 10% ethanol blends to 15% ethanol blends in the summer, effectively limiting summertime sales of
ethanol blends above 10% to FFVs from June 1 to September 15 each year. Notwithstanding, for the past four consecutive
years from 2022-2025, the President has directed the EPA to issue an emergency waiver to allow for the continued sale of
E15 during the June 1 to September 15 period.
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 change in Chevron precedent impacts how the EPA can administer the RFS, impose
limitations on the Treasury Department’s ability to promulgate regulations around IRA provisions, including SAF tax credits
and the 45Z Clean Fuel Production Credit, 45Q carbon capture and sequestration tax credits, EV tax credits and other clean
energy programs.
Similarly, should federal mandates regarding oxygenated gasoline be repealed, the market for domestic ethanol could be
adversely impacted. Economic incentives to blend based on the relative value of gasoline versus ethanol, taking into
consideration the octane value of ethanol, environmental requirements and the RFS mandate, may affect future demand. A
significant increase in supply of biofuels beyond the RFS mandated volumes could have an adverse impact on ethanol prices.
Moreover, changes to the RFS could negatively impact the price of ethanol or cause imported sugarcane or corn ethanol from
other countries to become more economical than domestic corn ethanol. Likewise, international, national, state and/or
regional LCFS programs like that of California, Oregon, Washington state or Canada could be favorable or harmful to U.S.
corn ethanol, depending on how the laws and regulations are crafted, enforced, interpreted, repealed and/or modified.
Future demand for ethanol is uncertain and changes in public perception, consumer acceptance and overall consumer
demand for transportation fuel could affect demand.
Today there are limited markets for ethanol beyond its value as an oxygenate domestically and abroad. We believe
further consumer acceptance of E15 and E85 fuels may be necessary before ethanol can achieve significant market share
growth in the U.S. Discretionary and E85 blending are important secondary markets. Discretionary blending is often
determined by the price of ethanol relative to gasoline, the value of RINs or other low-carbon fuel credits, and availability to
consumers. When discretionary blending is financially unattractive, the incremental demand for ethanol may be reduced.
New incentives for SAF or sustainable marine fuel could open new markets for ethanol.
Demand for ethanol is also affected by overall demand for surface transportation fuel, which is affected by cost, number
of miles traveled and vehicle fuel economy. Global events, such as international health epidemics, greatly decreased miles
traveled and in turn, the demand for ethanol. Consumer demand for gasoline may be impacted by various transportation
trends, such as widespread adoption of electric vehicles. Numerous automakers have announced plans to phase out the
production of gasoline and diesel powered vehicles by the mid-2030s. These announcements coincide with pledges to ban the
sale of internal combustion engines in countries such as Japan and the United Kingdom by 2035, as well as a statewide ban in
California. If realized, these bans would accelerate the decline of liquid fuel demand for surface transportation and by
extension demand for ethanol, biodiesel and renewable diesel.
Our risk management and commodity trading strategies could be ineffective and expose us to decreased liquidity.
As market conditions warrant, we use forward contracts to sell some of our ethanol, distillers grains, Ultra-High Protein,
and renewable corn oil, or buy some of the corn, and natural gas we need to partially offset commodity price volatility. We
also engage in other hedging transactions and other commodity trading involving exchange-traded futures contracts for corn,
natural gas, ethanol, soybean meal, soybean oil and other agricultural commodities. The financial impact of these activities
depends on the price of the commodities involved and/or our ability to physically receive or deliver the commodities.
Hedging arrangements expose us to risk of financial loss when the counterparty defaults on its contract or, in the case of
exchange-traded contracts, when the expected differential between the price of the underlying and physical commodity
changes. Hedging activities can result in losses when a position is purchased in a declining market or sold in a rising market.
Hedging losses may be offset by a decreased cash price for corn, and natural gas and an increased cash price for ethanol,
distillers grains, Ultra-High Protein and renewable corn oil. We vary the amount of hedging and other risk mitigation
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strategies we undertake and sometimes choose not to engage in hedging transactions at all. We cannot provide assurance that
our risk management and commodity trading strategies and decisions will be profitable or effectively offset commodity price
volatility. If they are not, our results of operations and financial position may be adversely affected.
The use of derivative financial instruments frequently involves cash deposits with brokers, or margin calls. Sudden
changes in commodity prices may require additional cash deposits immediately. Depending on our open derivative positions,
we may need additional liquidity with little advance notice to cover margin calls. While we continuously monitor our
exposure to margin calls, we cannot guarantee we will be able to maintain adequate liquidity to cover margin calls in the
future.
In the past, we have had operating losses and could incur future operating losses.
In the last five years, we incurred operating losses during certain quarters and annually and could incur operating losses
in the future that are substantial. Although we have had periods of sustained profitability, we may not be able to maintain or
increase profitability on a quarterly or annual basis, which could impact the market price of our common stock and the value
of your investment. In addition, periods of sustained losses create uncertainty as to whether some or all of our deferred tax
assets will be realizable in the future.
If the United States were to withdraw from or materially modify certain international trade agreements, our business,
financial condition and results of operations could be materially adversely affected.
Ethanol and other products that we produce are or have been exported to Canada, Mexico, Brazil, China and other
countries. Our business may be impacted by government policies, such as tariffs, duties, subsidies, import and export
restrictions and outright embargos. In early 2025, the Trump administration announced additional tariffs on various imports
from China, Mexico, and Canada, and signaled a willingness to renegotiate or withdraw from existing trade agreements.
These actions have prompted actual or threatened retaliatory measures against U.S. exports, including ethanol and
agricultural products in some cases. While the current administration’s efforts to counter trade barriers in certain countries
may ultimately benefit the ethanol industry (such as Brazil, where U.S. ethanol has been subject to tariffs since 2020), the
risk of reciprocal tariffs by other countries, including Canada and Mexico, may impede exported volumes. The outcome of
trade negotiations or lack thereof, has in previous year had, and may in the future have a material adverse effect on our
business, financial condition and results of operations.
Our indebtedness could negatively affect our financial condition, decrease our liquidity and impair our ability to operate the
business.
Our ability to make payments on and to refinance our debt will depend on our ability to generate cash in the future. Our
ability to generate cash is dependent on various factors; general economics, financial, competitive, legislative, regulatory and
other factors beyond our control. Certain of our long-term borrowings include provisions that require minimum levels of
working capital and equity and impose limitations on additional debt. Our ability to satisfy these provisions can be affected
by events beyond our control, such as the demand for and the fluctuating price of commodities. Noncompliance with these
provisions could result in the default and acceleration of long-term debt payments. If cash on hand is insufficient to pay our
obligations or margin calls as they come due, it could have an adverse effect on our ability to conduct business.
Disruptions in the credit market could limit our access to capital.
We may need additional capital to fund our growth or other business activities in the future. The cost of capital under our
existing or future financing arrangements could increase and affect our ability to trade with various commercial
counterparties or cause our counterparties to require additional forms of credit support. If capital markets are disrupted, we
may not be able to access capital at all or capital may only be available under less favorable terms.
Our production level may fluctuate due to planned and unplanned downtime at our assets.
Unplanned downtime may occur from time to time at our facilities. Our plants may not produce at yields we expect due
to a variety of reasons, including, but not limited to, equipment failures and other breakdowns; labor shortages; lack of
adequate raw materials, including corn supply; adverse pricing on raw materials and finished goods that becomes
uneconomical; poor rail service; lack of adequate storage, permitting or regulatory issues, adverse weather and other reasons.
Any of these production events may adversely impact our profitability and financial position.
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Our ability to maintain the required regulatory permits or manage changes in environmental, safety and TTB regulations is
essential to successfully operating our plants.
Our plants are subject to extensive air, water, environmental and TTB regulations. Our production facilities involve the
emission of various airborne pollutants, including particulate, carbon dioxide, nitrogen oxides, hazardous air pollutants and
volatile organic compounds, which requires numerous environmental permits to operate our plants. Governing state agencies
could impose costly conditions or restrictions that are detrimental to our profitability and have a material adverse effect on
our operations, cash flows and financial position.
Environmental laws and regulations at the federal and state level are subject to change. These changes can also be made
retroactively. It is possible that more stringent federal or state environmental rules or regulations could be adopted, which
could increase our operating costs and expenses. Consequently, even though we currently have the proper permits, we may be
required to invest or spend considerable resources in order to comply with future environmental regulations. Furthermore,
ongoing plant operations, which are governed by the Occupational Safety and Health Administration, may change in a way
that increases the cost of plant operations. Any of these events could have a material adverse effect on our operations, cash
flows and financial position.
TTB regulations apply when producing our undenatured ethanol. These regulations carry substantial penalties for non-
compliance and therefore any non-compliance may adversely affect our financial operations or adversely impact our ability
to produce undenatured ethanol.
Any inability to generate or obtain RINs could adversely affect our operating margins.
Under the RFS, biofuel producers generate different types of RINs to attach to each gallon produced depending on the
feedstock, pathway and level of GHG reduction. Cellulosic biofuel is assigned a D3 or D7 RIN, advanced biofuels such as
biodiesel and renewable diesel generate D4 RINs, advanced biofuels generate D5 RINs, and all other biofuels that do not
generate a D3, D4, D5 or D7 RIN qualify for a D6 RIN. Nearly all of our ethanol production is sold with D6 RINs that are
used by our customers to comply with their blending obligations under the RFS. Should our production practices not meet the
EPA’s requirements for RIN generation in the future, we would need to export the ethanol, purchase RINs in the open market
or sell our ethanol at a discounted price to compensate for the absence of RINs. Likewise, our renewable corn oil must meet
regulatory requirements to be suitable as a feedstock for the production of renewable diesel, biodiesel and SAF, and changing
production practices or regulations could impact its suitability as a feedstock. The price of RINs depends on a variety of
factors, including the availability of qualifying biofuels and RINs for purchase, production levels of transportation fuel and
percentage mix of ethanol with other fuels, and cannot be predicted. The values of D6 RINs, for which most conventional
corn ethanol qualifies, have varied from a few pennies to well over a dollar. Failure to obtain sufficient RINs or reliance on
invalid RINs could subject us to fines and penalties imposed by the EPA which could adversely affect our results of
operations, cash flows and financial condition.
As we trade ethanol acquired from third-parties, should it be discovered the RINs associated with the ethanol we
purchased are invalid, albeit unknowingly, we could be subject to substantial penalties if we are assessed the maximum
amount allowed by law. Based on EPA penalties assessed on RINs violations in the past few years, in the event of a violation,
the EPA could assess penalties, which could have an adverse impact on our profitability.
Compliance with evolving environmental, health and safety laws and regulations, particularly those related to climate
change, could be costly.
Our plants emit biogenic carbon dioxide from fermentation as a by-product of ethanol production. While all nine of our
plants have grandfathered RFS pathways allowing them to operate under their current authorized capacity under their EPA
approved grandfathered limits, operating above these capacities requires an Efficient Producer Pathway, demonstrating at
least a 20% reduction in GHG emissions relative to petroleum-based gasoline from a 2005 baseline. Four of our plants
currently maintain Efficient Producer Pathways to operate at increased capacities.
To expand our production capacity, federal and state regulations may require us to obtain additional permits, achieve
EPA’s efficient producer status under the pathway petition program, install advanced technology or reduce drying distillers
grains. Compliance with future laws or regulations to decrease carbon dioxide could be costly and may prevent us from
operating our plants as profitably, which may have an adverse impact on our operations, cash flows and financial position.
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We may fail to realize the anticipated benefits of mergers, acquisitions, joint ventures or partnerships.
We continuously look for opportunities to enhance our existing businesses through strategic acquisitions. The process of
integrating an acquired business into our existing business and operations may result in unforeseen operating difficulties and
expenditures as well as require a significant amount of management resources. There is also the risk that our due diligence
efforts may not uncover significant business flaws or hidden liabilities. In addition, we may not realize the anticipated
benefits of an acquisition or joint venture and they may not generate the anticipated financial results.
Future acquisitions may involve issuing equity as payment or to finance the business or assets, which could dilute your
ownership interest. Furthermore, additional debt may be necessary to complete these transactions, which could have a
material adverse effect on our financial condition.
Future events could result in impairment of long-lived assets, which may result in charges that adversely affect our results of
operations.
Long-lived assets, including property, plant and equipment, intangible assets, goodwill and equity method investments,
are evaluated for impairment annually or whenever events or changes in circumstances indicate that the carrying amount of
an asset may not be recoverable. Our impairment evaluations are subject to changes in key assumptions used in our analysis
and may require use of financial estimates of future cash flows. Application of alternative assumptions could produce
significantly different results. We may be required to recognize impairments of long-lived assets based on future economic
factors such as unfavorable changes in estimated future undiscounted cash flows of an asset group.
Global competition could affect our profitability.
We compete with producers in the United States and abroad. Depending on feedstock, labor and other production costs,
producers in other countries, such as Brazil, may be able to produce ethanol, corn oil and distillers grains cheaper or with a
lower CI than we can. Under the RFS, certain parties are obligated to meet an advanced biofuel standard. While
transportation costs, infrastructure constraints, currency valuations and demand may temper the impact of ethanol imports,
foreign competition remains a risk to our business. Moreover, significant additional foreign ethanol production could create
excess supply, which could result in lower ethanol prices throughout the world, including the United States. Penetration of
ethanol or distillers grains imports into the domestic or international market may have a material adverse effect on our
operations, cash flows and financial position.
International activities such as boycotts, embargoes, product rejection, trade policies and compliance matters, may have an
adverse effect on our results of operations.
Government actions abroad can have a significant impact on our business. We have experienced trade policy disputes,
tariffs, changing foreign laws as well as investigations in various foreign countries over the past ten years that have adversely
impacted the international demand for U.S. ethanol. With these types of international activities, the value of our products may
be affected, which could have a negative impact on our profitability. Additionally, tariffs on U.S. ethanol may lead to further
industry over-supply and reduce our profitability. Moreover, the America First trade position has caused more countries to
toughen their positions on U.S. imports.
Increased ethanol industry penetration by oil and other multinational companies could impact our margins.
We operate in a very competitive environment and compete with other domestic ethanol producers in a relatively
fragmented industry. We compete for capital, labor, corn, shipping and other resources with these companies. Historically, oil
companies, petrochemical refiners and gasoline retailers were not engaged in ethanol, biodiesel and other biofuel production
even though they form the primary distribution network for finished liquid fuels. If these companies continue to increase their
ethanol plant ownership or additional companies commence production, the need to purchase ethanol from independent
producers like us or at pricing that provides us an acceptable margin could diminish and adversely affect our operations, cash
flows and financial position. Integrated oil companies and merchant refiners are increasingly investing in retrofitting
refineries or building new refineries to produce renewable diesel, and partnering with commodity processors to supply
soybean oil, distillers corn oil and other feedstocks, which could adversely impact the market for our renewable corn oil,
distillers grains and Ultra-High Protein.
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Our agribusiness operations are subject to significant government regulations.
Our agribusiness operations are regulated by various government entities that can impose significant costs on our
business. Failure to comply could result in additional expenditures, fines or criminal action. Our production levels, markets
and grains we merchandise are affected by federal government programs. Government policies such as tariffs, duties,
subsidies, import and export restrictions, tax incentives, commodity support programs, conservation incentives, fuel and
vehicle standards and embargos can also impact our business. Changes in government policies and producer support could
impact the type and amount of grains planted, which could affect our ability to buy grain. Export restrictions or tariffs could
limit sales opportunities outside of the United States.
Commodities futures trading is subject to extensive regulations.
The futures industry is subject to extensive regulation. In addition to trading physical commodities, the company may
engage in trading of futures, forward and options contracts, and other derivative instruments. As a market participant, we are
subject to regulation concerning trade practices, business conduct, reporting, position limits, record retention, the conduct of
our officers and employees, and other matters. Since we use exchange-traded futures contracts as part of our business, we are
subject to the Commodity Exchange Act and are required to comply with a wide range of requirements imposed by the
CFTC, FERC, National Futures Association and the exchanges on which we trade.
Among other requirements, the CFTC and certain exchanges have established limits on the maximum net long and net
short positions that may be held or controlled in particular commodities. The company currently maintains a hedge
exemption through the CME Group for corn traded on the CBOT exchange, increasing the allowable long and short futures
positions that may be held during the spot and single/all month periods. Due to rules imposed by the FERC under the Natural
Gas Act, the company has enacted limitations on the size of financial positions that may be held when a physical position is
held contemporaneously within a given market location.
Failure to comply with the laws, rules or regulations applicable to futures trading could have adverse consequences. Such
claims could result in fines, settlements or suspended trading privileges, which could have a material adverse impact on our
business, financial condition or operating results.
Our success depends on our ability to manage our changing operations.
Since our formation in 2004, our business has changed significantly in size, products and complexity. These changes
place substantial demands on our management, systems, internal controls, and financial and physical resources. If we acquire
or develop additional operations, implement new technologies, sell into new markets, track the CI of the feedstocks we
purchase and finished products we sell, we may need to further develop our financial and managerial controls and reporting
systems, and could incur expenses related to hiring additional qualified personnel and expanding our information technology
infrastructure. Our ability to manage change and/or growth effectively could impact our results of operations, financial
position and cash flows.
New ethanol process technologies could emerge that require less energy per gallon to produce or increase yields of
various products and in some cases develop new co-products and result in lower production costs or more favorable
economics for a plant. Our process technologies could become less effective or competitive than competing technologies or
become obsolete and place us at a competitive disadvantage, which could have a material adverse effect on our operations,
cash flows and financial position. Newly constructed plants could operate more efficiently and reliably than the legacy fleet
of plants constructed approximately 20 years ago, which includes our assets, putting us at a competitive disadvantage.
Competitors could successfully deploy carbon capture technology and achieve lower CI scores before we are able to do so,
which could put us at a competitive disadvantage, and adversely affect our operations, financial position and cash flows.
We may be required to provide remedies for ethanol, distillers grains, Ultra-High Protein or renewable corn oil that do not
meet the specifications defined in our sales contracts.
If we produce or purchase ethanol, distillers grains, Ultra-High Protein or renewable corn oil that does not meet the
specifications defined in our sales contracts, we may be subject to quality claims. We could be required to refund the
purchase price of any non-conforming product or replace the non-conforming product at our expense. Ethanol, distillers
grains, Ultra-High Protein or renewable corn oil that we purchase or market and subsequently sell to others could result in
similar claims if the product does not meet applicable contract specifications, which could have an adverse impact on our
profitability.
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Business disruptions due to unforeseen operational failures or factors outside of our control could impact our ability to fulfill
contractual obligations.
Natural disasters, pandemics, transportation issues, significant track damage resulting from a train derailment, aging
equipment breakdowns, coupled with supply chain challenges impacting repairs or replacements, or labor strikes by our
transportation providers could adversely impact operations and/or delay shipments of raw materials to our plants or deliveries
of ethanol, distillers grains, Ultra-High Protein and renewable corn oil to our customers. If we are unable to meet customer
demand or contract delivery requirements due to stalled operations caused by business disruptions, we could potentially lose
customers or volume with such customers.
Shifts in global markets, supply or demand changes, as well as adverse weather conditions, such as inadequate or
excessive amounts of rain during the growing season, overly wet conditions, hail, derecho wind events, an early freeze or
snowy weather during harvest could impact the supply of corn that is needed to produce ethanol. Corn stored in a temporary
open pile may be damaged by rain or warm weather before the corn is dried, shipped or moved into a permanent storage
structure. Any such change or conditions could adversely affect our profitability.
Our ethanol-related assets may be at greater risk of terrorist attacks, threats of war or actual war, than other possible targets.
Terrorist attacks in the United States, including threats of war or actual war, may adversely affect our operations. A direct
attack on our ethanol plants, storage facilities, fuel terminals and railcars could have a material adverse effect on our financial
condition, results of operations and cash flows. Furthermore, a terrorist attack could have an adverse impact on ethanol
prices. Disruption or significant increases in ethanol prices could result in government-imposed price controls.
Our network infrastructure, enterprise applications and internal technology systems could be damaged or otherwise fail and
disrupt business activities.
Our network infrastructure, enterprise applications and internal technology systems are instrumental to the day-to-day
operations of our business. Numerous factors outside of our control, including earthquakes, floods, lightning, tornados, fire,
power loss, telecommunication failures, computer viruses, physical or electronic vandalism or similar disruptions could result
in system failures, interruptions or loss of critical data and prevent us from fulfilling customer orders. We cannot provide
assurance that our backup systems are sufficient to mitigate hardware or software failures, which could result in business
disruptions that negatively impact our operating results and damage our reputation.
We could be adversely affected by cyber-attacks, data security breaches and significant information technology systems
interruptions.
We rely on network infrastructure, enterprise applications, and internal and external technology systems for operational,
marketing support and sales, and product development activities. The hardware and software systems related to such
activities are subject to damage from earthquakes, floods, lightning, tornados, fire, power loss, telecommunication failures,
cyber-attacks and other similar events. They are also subject to acts such as computer viruses, physical or electronic
vandalism or other similar disruptions that could cause system interruptions and loss of critical data, and could prevent us
from fulfilling customers’ orders. We have experienced various cyber-attacks, with minimal consequences on our business to
date. As examples, we have experienced attempts to gain access to systems, denial of service attacks, attempted malware
infections, account takeovers, scanning activity and phishing emails. Attacks can originate from external criminals, terrorists,
nation states or internal actors.
We will continue to dedicate resources and incur expenses to maintain and update on an ongoing basis the systems and
processes that are designed to mitigate the information security risks we face and protect the security of our computer
systems, software, networks and other technology assets against attempts by unauthorized parties to obtain access to
confidential information, disrupt or degrade service or cause other damage. We have implemented numerous cybersecurity
measures, including but not limited to, ongoing collaboration and engagement with the Department of Homeland Security,
access controls, data encryption, internal and third-party vulnerability assessments, employee training, continuous protection
and monitoring, and maintenance of backup and protective systems. Our information technology systems may still be
vulnerable to cybersecurity threats and other electronic security breaches. While we have taken reasonable efforts to protect
ourselves, we cannot assure our shareholders that our security measures would be sufficient in the future. Any event that
causes failures or interruption in such hardware or software systems could result in disruption of our business operations,
have a negative impact on our operating results, and damage our reputation, which could negatively affect our financial
condition, and results of operation.
24
We may not be able to hire and retain qualified personnel to operate our facilities.
Our success relies on our ability to attract and retain skilled and capable employees. Each of our locations, as well as our
corporate office, requires qualified professionals across key roles, including but not limited to engineering, merchandising,
finance, accounting, management, and other critical functions. If we are unable to hire and retain top talent, we may not be
able to maximize production, optimize plant operations and effectively execute our business strategy.
Compliance with and changes in tax laws could adversely affect our performance.
We are subject to extensive tax liabilities imposed by multiple jurisdictions, including income taxes, indirect taxes
(excise/duty, sales/use, gross receipts, and value-added taxes), 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. Subsequent changes to our tax liabilities as a result of these audits may
subject us to interest and penalties. Tax incentives for producing low-carbon fuels may add additional complexity to our
business, and our ability to qualify for them relative to other producers may put us at a competitive disadvantage.
Federal, state and local jurisdictions may challenge our tax return positions.
The positions taken in our federal and state tax return filings require significant judgments, use of estimates and the
interpretation and application of complex tax laws. Significant judgment is also required in assessing the timing and amounts
of deductible and taxable items. Despite management’s belief that our tax return positions are fully supportable, certain
positions may be successfully challenged by federal, state and local jurisdictions, adversely affecting our financial position.
Financial performance of our equity method investments are subject to risks beyond our control and can vary substantially
from period to period.
The company invests in certain limited liability companies, which are accounted for using the equity method of
accounting. This means that the company’s share of net income or loss in the investee increases or decreases, as applicable,
the carrying value of the investment. By operating a business through this arrangement, we do not have control over
operating decisions as we would if we owned the business outright. Specifically, we cannot act on major business initiatives
without the consent of the other investors.
The company recognizes these investments within other assets on the consolidated balance sheets and its proportionate
share of earnings on a separate line item in the consolidated statements of operations. As a result, the amount of net
investment income recognized from these investments can vary substantially from period to period. Any losses experienced
by these entities could adversely impact our results of operations and the value of our investment.
We are exposed to credit risk that could result in losses or affect our ability to make payments should a counterparty fail to
perform according to the terms of our agreement.
We are exposed to credit risk from a variety of customers, counterparties, including major integrated oil companies, large
independent refiners, petroleum wholesalers, marketing companies and other ethanol plants. We are also exposed to credit
risk with major suppliers of petroleum products and agricultural inputs when we make payments for undelivered inventories.
Our fixed-price forward contracts are subject to credit risk when prices change significantly prior to delivery. The inability by
a third party to pay us for our sales, provide product that was paid for in advance or deliver on a fixed-price contract could
result in a loss and adversely impact our liquidity and ability to make our own payments when due.
We have limitations, as a holding company, in our ability to receive distributions from a small number of our subsidiaries.
We conduct most of our operations through our subsidiaries and rely on dividends or intercompany transfers of funds to
generate free cash flow. Some of our subsidiaries are currently, or are expected to be, limited in their ability to pay dividends
or make distributions under the terms of their financing agreements. Consequently, we cannot fully rely on the cash flow
from one subsidiary to satisfy the loan obligations of another subsidiary. As a result, if a subsidiary is unable to satisfy its
loan obligations, we may not be able to prevent default by providing additional cash to that subsidiary, even if sufficient cash
exists elsewhere within our organization.
The ability of suppliers to deliver inputs, parts, components and equipment to our facilities, and our ability to construct our
25
facilities without disruption, could affect our business performance.
We use a wide range of materials and components in the production of our products and our transformation construction,
which come from numerous suppliers. Also, key parts may be available only from a single or a limited group of suppliers,
and we are subject to supply and pricing risk. Our operations and those of our suppliers are subject to disruption for a variety
of reasons, including supplier plant shutdowns or slowdowns, parts availability, transportation delays, work stoppages, labor
relations, governmental regulatory and enforcement actions, disputes with suppliers, distributors or transportation providers,
information technology failures, and natural hazards, including due to climate change. We may be impacted by supply chain
issues, due to factors largely beyond our control, which could escalate in future quarters. Any of the foregoing factors may
result in higher costs, operational disruptions or construction delays, which could have an adverse impact on our business and
financial statements. Such disruption has in the past and could in the future interrupt our ability to manufacture certain
products. Any significant disruption could have a material adverse impact on our financial statements.
Inflation may impact the cost and/or availability of materials, inputs and labor, which could adversely affect our operating
results.
We have experienced inflationary impacts on raw materials, labor costs, wages, components, equipment, other inputs and
services across our business and inflation and its impact could escalate in future quarters, many of which are beyond our
control. Moreover, we may not be able to pass those costs along in the products we sell. As such, inflationary pressures could
have a material adverse effect on our performance and financial statements.
Climate change, environmental, social and corporate governance issues and uncertainty regarding regulation of such matters
may increase our operating costs, impact our capital markets and potentially reduce the value of our products and assets.
The issue of global climate change continues to attract considerable public and scientific attention with widespread
concern about the impacts of human activity, especially the emissions of GHG such as carbon dioxide and methane. Climate
change legislation in the U.S. is likely to receive increased focus and consideration over the next several decades, with
numerous proposals having been made and are likely to continue to be made at the international, national, regional and state
levels of government that are intended to limit emissions of GHG and capture carbon. Several states have already adopted
measures requiring reduction of GHG within state boundaries. Other states have elected to participate in voluntary regional
cap-and-trade programs, low-carbon fuel standards and low-carbon energy requirements. While we have considered potential
risks with transitioning to a low-carbon economy, and we believe our products are low carbon and result in a reduction of
GHG emissions compared to alternatives, any significant legislative changes at the international, national, state or local levels
could significantly affect our ability to produce and sell our products, could increase the cost of the production and sale of our
products and could materially reduce the value of our products. Additionally, our industry receives adverse commentary
related to food versus fuel and land use change/conversion debates. These debates could increase which could potentially
result in increased costs and/or regulations. Moreover, costs to transition to lower emissions process technology related to our
decarbonization strategy is a related risk that has the potential to result in increased research and development expenditures in
new and alternative technologies and capital investments in technology development. Unsuccessful investment in new
technologies could pose further risk. Transitioning to a low-carbon economy could also result in increased cost of raw
materials, which could increase our overall production costs.
Apart from legislation and regulation, some banks based both domestically and internationally have announced that they
have adopted non-financial metrics for evaluating companies on their environmental impact, governance structure, and other
criteria. There have also been efforts in recent years affecting the investment community promoting the divestment of fossil
fuel equities, and encouraging the consideration of environmental factors in evaluating companies. While we have made
improvements to our corporate governance, and continue to reduce the environmental impact of our operations and
ingredients, these trends may adversely affect the demand for and price of securities issued by us, and impact our access to
the capital and financial markets.
Further, it is believed that climate change itself may cause more extreme temperatures and weather conditions such as
more intense hurricanes, thunderstorms, tornadoes, droughts, floods, snow or ice storms as well as rising sea levels and
increased volatility in temperatures. Extreme weather conditions can interfere with our operations and cause damage resulting
from extreme weather, which may not be fully insured. However, at this time, we are unable to determine the extent to which
any potential climate change may lead to increased weather hazards affecting our operations.
26
Our insurance policies do not cover all losses, costs or liabilities that we may experience, and insurance companies that
currently insure companies in the energy industry may cease to do so or substantially increase premiums.
We are insured under property, liability and business interruption policies, subject to the deductibles and limits under
those policies. We have acquired insurance that we believe to be adequate to prevent loss from material foreseeable risks.
However, events may occur for which no insurance is available for some or all of the loss or for which insurance is not
available on terms that are acceptable. Loss from an event, such as, but not limited to war, riots, pandemics, terrorism or other
risks, may not be insured and such a loss may have a material adverse effect on our operations, cash flows and financial
position. Certain of our ethanol plants and our related storage tanks, as well as certain of our fuel terminal facilities are
located within recognized seismic and flood zones. We believe that the design of these facilities have been modified to fortify
them to meet structural requirements for those regions of the country. We have also obtained additional insurance coverage
specific to earthquake and flood risks for the applicable plants and fuel terminals. However, there is no assurance that any
such facility would remain in operation if a seismic or flood event were to occur.
Additionally, our ability to obtain and maintain adequate insurance may be adversely affected by conditions in the
insurance market over which we have no control. In addition, if we experience insurable events, our annual premiums could
increase further or insurance may not be available at all. If significant changes in the number or financial solvency of
insurance underwriters for the ethanol industry occur, we may be unable to obtain and maintain adequate insurance at a
reasonable cost. We cannot assure our shareholders that we will be able to renew our insurance coverage on acceptable terms,
if at all, or that we will be able to arrange for adequate alternative coverage in the event of non-renewal. The occurrence of an
event that is not fully covered by insurance, the failure by one or more insurers to honor its commitments for an insured event
or the loss of insurance coverage could have a material adverse effect on our financial condition, results of operations, cash
flows.
Risks Related to our Common Stock
The price of our common stock may be highly volatile and subject to factors beyond our control.
Some of the many factors that can influence the price of our common stock include: (1) our results of operations and the
performance of our competitors; (2) public’s reaction to our press releases, public announcements and filings with the SEC;
(3) changes in earnings estimates or recommendations by equity research analysts who follow us or other companies in our
industry; (4) changes in general economic conditions; (5) changes in market prices for our products or raw materials and
related substitutes; (6) sales or purchases of common stock by our directors, executive officers and significant shareholders;
(7) actions by institutional investors trading in our stock; (8) disruptions in our operations; (9) changes in our management
team; (10) other developments affecting us, our industry or our competitors; and (11) U.S. and international economic, legal
and regulatory factors unrelated to our performance. The stock market may experience significant price and volume
fluctuations, which are unrelated to the operating performance of any particular company. These broad market fluctuations
could materially reduce the price of our common stock price based on factors that have little or nothing to do with our
company or its performance.
Anti-takeover provisions could make it difficult for a third party to acquire us.
Our restated articles of incorporation, restated bylaws and Iowa’s law contain anti-takeover provisions that could delay
or prevent change in control of us or our management. These provisions discourage proxy contests, making it difficult for our
shareholders to take other corporate actions without the consent of our board of directors, which include: (1) board members
can only be removed for cause with an affirmative vote of no less than two-thirds of the outstanding shares; (2) shareholder
action can only be taken at a special or annual meeting, not by written consent except where required by Iowa law; (3)
shareholders are restricted from making proposals at shareholder meetings; and (4) the board of directors can issue authorized
or unissued shares of stock. We are subject to the provisions of the Iowa Business Corporations Act, which prohibits
combinations between an Iowa corporation whose stock is publicly traded or held by more than 2,000 shareholders and an
interested shareholder for three years unless certain exemption requirements are met.
Provisions in the convertible notes could also make it more difficult or too expensive for a third party to acquire us. If a
takeover constitutes a fundamental change, holders of the notes have the right to require us to repurchase their notes in cash.
If a takeover constitutes a make-whole fundamental change, we may be required to increase the conversion rate for holders
who convert their notes. In either case, the obligation under the notes could increase the acquisition cost and discourage a
third party from acquiring us. These items discourage transactions that could otherwise command a premium over prevailing
market prices and may limit the price investors are willing to pay for our stock.
27
Non-U.S. shareholders may be subject to U.S. income tax on gains related to the sale of their common stock.
If we are a U.S. real property holding corporation during the shorter of the five-year period before the stock was sold or
the period the stock was held by a non-U.S. shareholder, the non-U.S. shareholder could be subject to U.S federal income tax
on gains related to the sale of their common stock. Whether we are a U.S. real property holding corporation depends on the
fair market value of our U.S. real property interests relative to our other trade or business assets and non-U.S. real property
interests. We cannot provide assurance that we are not a U.S. real property holding corporation or will not become one in the
future.
Item 1B. Unresolved Staff Comments.
None.
Item 1C. Cybersecurity.
Risk Management and Strategy
We promote a company-wide culture of cybersecurity risk management to ensure that cybersecurity risk considerations
are an integral part of decision-making at all organizational levels. To protect the confidentiality, integrity and availability of
our data and information systems, we have implemented cyber defenses and continuously enhance them to address evolving
threats. Our information technology (IT) department actively monitors and evaluates our cybersecurity practices to ensure
alignment with our business objectives and operational needs. Our cybersecurity program is comprehensive in scope and
covers the systems supporting all our business operations.
Our program is built on industry-standard frameworks, including the National Institute of Standards and Technology, and
the Cybersecurity and Infrastructure Security Agency. We also follow applicable federal and state statutory and regulatory
guidance and have adopted internal policies and standards in alignment with these federal and state requirements.
Furthermore, we collaborate with external experts, consultants and auditors in routinely evaluating and testing our
information systems controls. We have regular CISA vulnerability scans and cyber table-top exercises to help us test and
refine our formal Cyber Incident Response Plan.
We maintain a well-documented process to oversee cybersecurity risks associated with our third-party service providers.
We evaluate our third parties prior to any engagements and review their System and Organization Controls reports to obtain
reasonable assurance that their controls meet our security standards.
Our IT policies communicate our expectations for employees and contractors regarding the security of our IT systems.
We perform annual cyber security and technology processes training programs and regular third-party phishing campaigns to
raise awareness of potential threats.
Governance
The Audit Committee of the Board of Directors has oversight of management's efforts with respect to IT systems and
cybersecurity. As part of this oversight, the company's IT leader meets on a quarterly basis with the Audit Committee and on
an annual basis with the company's Board of Directors. During these update meetings, IT provides the Audit Committee and
Board of Directors updates regarding any changes around our cyber defenses, ongoing IT initiatives, and emerging threats
and plans to pro-actively counter these threats.
Management continuously monitors the effectiveness of our cybersecurity defenses and invests in regular, ongoing
cybersecurity training for both our IT department and the organization overall. Our Director of IT Security brings over 25
years of cybersecurity experience, including an Information Technology Infrastructure background, Information Security
Officer responsibilities, and experience managing multi-tier secure networks in the United States Air Force. Similarly, our
Director of IT Infrastructure brings over 25 years of experience spanning a broad range of technologies.
As of December 31, 2025, we have not identified an indication of a cybersecurity incident that would have a material
impact on our business and consolidated financial statements.
28
Item 2. Properties.
We believe the properties owned and leased at our locations are sufficient to accommodate our current needs, as well as
potential expansion.
Corporate
We lease approximately 54,000 square feet of office space in Omaha, Nebraska for our corporate headquarters, which
houses our corporate administrative functions and commodity trading operations.
Ethanol Production Segment
We own approximately 1,369 acres of land and lease approximately 79 acres of land at and around our ethanol
production facilities. Additionally, we lease approximately five acres of land at a fuel terminal facility. As detailed in our
discussion of the ethanol production segment in Item 1 – Business, our ethanol plants have the capacity to produce
approximately 850 million gallons of ethanol per year.
Agribusiness and Energy Services Segment
As detailed in our discussion in Item 1 – Business, our agribusiness and energy services segment facilities include grain
storage capacity at our ethanol plants of approximately 12.0 million bushels.
Our marketing operations are conducted primarily at our corporate office, in Omaha, Nebraska.
Item 3. Legal Proceedings.
We are currently involved in litigation that has occurred in the ordinary course of doing business. We do not believe this
will have a material adverse effect on our financial position, results of operations or cash flows.
Item 4. Mine Safety Disclosures.
Not applicable.
29
PART II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity
Securities.
Common Stock
Our common stock trades under the symbol “GPRE” on Nasdaq.
Holders of Record
We had 1,612 holders of record of our common stock, not including beneficial holders whose shares are held in names
other than their own, on February 6, 2026. This figure does not include approximately 67.2 million shares held in depository
trusts.
Dividend Policy
In order to retain and direct cash flow to the company’s operating strategy, the deployment of the company's carbon
strategy and other corporate purposes, the company did not pay a cash dividend on its shares of common stock for the years
ended December 31, 2025 and 2024, respectively. The company does not anticipate declaring cash dividends on its common
stock for the foreseeable future.
Issuer Purchases of Equity Securities
Employees and directors may surrender shares when restricted stock grants are vested to satisfy statutory minimum
required payroll tax withholding obligations. The following table lists the shares that were surrendered during the fourth
quarter of 2025:
Period
Total Number of
Shares Withheld
Average Price
Paid per Share
October 1 - October 31
645 $
9.08
November 1 - November 30
6,297
10.29
December 1 - December 31
—
—
Total
6,942 $
10.18
Our board of directors authorized a share repurchase program of up to $200.0 million of our common stock. Under this
program, we may repurchase shares in open market transactions, privately negotiated transactions, accelerated buyback
programs, tender offers or by other means. The timing and amount of the transactions are determined by management based
on its evaluation of market conditions, share price, legal requirements and other factors. The program may be suspended,
modified or discontinued at any time, without prior notice. The company repurchased 2.9 million shares of its common stock
for a total of $30.0 million under the repurchase program during the year ended December 31, 2025. Since inception, the
company has repurchased 10.3 million shares of common stock for approximately $122.8 million under the program. At
February 10, 2026, $77.2 million in share repurchase authorization remained.
Recent Sales of Unregistered Securities
None.
Equity Compensation Plans
Refer to Item 12 – Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
for information regarding shares authorized for issuance under equity compensation plans.
30
Performance Graph
The following graph compares our cumulative total return with the S&P SmallCap 600 Index and the Nasdaq Clean
Edge Green Energy Index (CELS) for each of the five years ended December 31, 2025. The graph assumes a $100
investment in our common stock and each index at December 31, 2020, and that all dividends were reinvested.
*$100 invested on 12/31/20 in stock or index, including reinvestment of dividends.
Fiscal year ending December 31.
12/20
12/21
12/22
12/23
12/24
12/25
Green Plains Inc.
$
100.00 $
263.93 $
231.59 $
191.50 $
71.98 $
74.41
S&P SmallCap 600
100.00
126.82
106.40
123.48
134.22
142.30
Nasdaq Clean Edge Green Energy
100.00
97.36
68.01
61.27
49.71
65.63
The information in the graph will not be considered solicitation material, nor will it be filed with the SEC or incorporated
by reference into any future filing under the Securities Act or the Exchange Act, unless we specifically incorporate it by
reference into our filing.
Item 6. Reserved.
31
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
General
The following discussion and analysis includes information management believes is relevant to understand and assess
our consolidated financial condition and results of operations. This section should be read in conjunction with our
consolidated financial statements, accompanying notes and the risk factors contained in this report.
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. Today, our focus is to continue operating
safely, efficiently and cost-effectively while reducing the CI of our products and maintaining financial flexibility to support
long-term growth. During the year, under new leadership, the company completed targeted asset sales, strengthened liquidity
and reduced debt, positioning Green Plains to capture value from the next phase of the low-carbon transition. Our streamlined
platform is positioned to create value through our focus on operational excellence, continuous improvement and disciplined
capital allocation.
Our carbon reduction strategy plays a central role in achieving lower CI biofuel production and participation in various
clean fuel programs. Carbon capture and storage ("CCS") is operational at our three Nebraska facilities. These plants are
connected to the Tallgrass Trailblazer CO2 Pipeline, while our Iowa and Minnesota locations are committed to CCS through
Summit Carbon Solutions, which publicly projects operations commencing in 2028. CCS initiatives are expected to
significantly lower CI across our platform. Further, the company has purchased RECs to lower CIs at certain plants. Based on
current CI score estimates, all eight operational Green Plains facilities are expected to qualify for the Section 45Z Clean Fuel
Production Credit beginning in 2026, with six facilities qualifying in 2025, inclusive of three non-CCS facilities. In addition,
we are collaborating with global partners to explore innovative options for carbon use where pipeline transport or direct
injection may not be feasible. Reducing the CI of our fuel ethanol could allow us to benefit from state and federal clean fuel
programs, including LCFS and federal tax credits under the IRA and OBBB, and could position our low-carbon ethanol as a
potential feedstock for ATJ pathways to produce SAF.
We have installed and are operating FQT MSC™ technology at four of our biorefineries. Through our value-added
ingredients initiative, we produce Ultra-High Protein, a feed ingredient with protein concentrations of 50% or greater and
yeast concentrations of 25%, and increase production of renewable corn oil. We successfully completed full scale 60%
protein production runs using FQT's MSC™ system, which is our new specialty feed ingredient branded as Sequence™.
In September 2022, we broke ground at our biorefinery in Shenandoah, Iowa, as the first location to deploy FQT's
CST™ at commercial scale, and during 2024 the company successfully commissioned the CST™ equipment in the
Shenandoah facility. FQT's CST™ technology allows for the production of both food and industrial grade dextrose at a dry
mill ethanol plant to target applications in food production, in addition to serving as a feedstock for renewable chemicals and
synthetic biology. The facility has a rated capacity of 60 million pounds of product per year. The facility has been idled since
the first quarter of 2025 as the company focuses on optimizing its product mix to maximize current returns. The decision to
temporarily pause operations presents an opportunity to make some related infrastructure improvements, which would
require additional investment.
Additionally, we have taken advantage of opportunities to divest certain assets to reallocate capital toward our current
growth initiatives. We are focused on generating stable and growing operating margins through our business segments and
risk management strategy.
SAF is a drop-in fuel, chemically identical to petroleum-based jet fuel and can be blended into the fuel supply at varying
levels. There is an increasing focus on using this fuel to reduce the carbon footprint of air travel. SAF can be produced from
vegetable and waste oil feedstocks, such as our renewable corn oil. Additionally, ATJ technologies are emerging and being
commercialized that use low-CI ethanol as a feedstock to produce SAF.
32
In July 2023, we announced a technology collaboration with Equilon Enterprises LLC, which allows us to use FQT’s
precision separation and processing technology with Shell Fiber Conversion Technology. The two technologies will combine
fermentation, mechanical separation and processing, and fiber conversion into one platform. This has the potential to create a
new process to liberate nearly all available distillers corn oil currently bound in the fiber fraction of the corn kernel, generate
cellulosic sugars for production of low-carbon ethanol, and enhance and expand available high protein to produce high-
quality ingredients for global animal feed diets. The large-scale demonstration facility is operational and technology and
product development has continued to advance through 2025.
Our profitability is highly dependent on commodity prices, particularly for ethanol, distillers grains, Ultra-High Protein,
renewable 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 variety of risk management tools and hedging strategies to
monitor price risk exposure at our ethanol plants and lock in favorable margins or reduce production when margins are
compressed. Our profitability could be significantly impacted by price movements of the aforementioned commodities.
More information about our business, properties and strategy can be found under Item 1 – Business and a description of
our risk factors can be found under Item 1A – Risk Factors.
Industry Factors Affecting our Results of Operations
U.S. Ethanol Supply and Demand
According to the EIA, domestic ethanol production averaged 1.1 million barrels per day during both 2025 and 2024.
Refiner and blender input volume was 893 thousand barrels per day for 2025, which was consistent with the 895 thousand
barrels per day in 2024. Gasoline demand was consistent compared to the prior year at 8,802 thousand barrels per day in
2025. U.S. domestic ethanol ending stocks decreased by approximately 0.7 million barrels compared to the prior year to 22.9
million barrels as of December 31, 2025.
Global Ethanol Supply and Demand
According to the USDA Foreign Agriculture Service, domestic ethanol exports through October 31, 2025, were
approximately 1,750 mmg, which was 14% higher than 1,532 mmg for the same period of 2024. Canada was the largest
export destination for U.S. ethanol accounting for approximately 37% of domestic ethanol export volume, driven in part by
their national clean fuel standard. The Netherlands, the United Kingdom, India and Columbia accounted for approximately
16%, 9%, 9% and 6%, respectively, of U.S. ethanol exports. We currently estimate that net ethanol exports will range from
2.1 to 2.3 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
We continue to believe that over time demand will outpace supply leading to higher co-product returns. 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 precipitously since the advent of our transformation, so too has the production
of vegetable proteins from multiple companies in an effort to capitalize on this trend, most notably in U.S. soy crushing
capacity, which has led to an over-supplied domestic market and compressed protein values. 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 fourth quarter of 2025, soybean crush was 669 million bushels, up 69
million bushels from the 600 million bushels crushed during the fourth quarter of 2024. Soybean oil stocks were at 1.64
billion pounds as of December 31, 2025, which was up from the 1.24 billion pounds of stocks as of December 31, 2024.
Soybean meal production was 15.9 million short tons for the fourth quarter of 2025, up from the 14.2 million short tons from
the same period in the prior year.
33
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 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. Sales of EVs in the U.S. were approximately 1.3
million vehicles during 2025, which represented approximately 7.8% of new vehicles sales, up from 8.1% in 2024. Transition
of the light duty surface transportation fleet from internal combustion engines to EVs could decrease the demand for ethanol.
The Clean Fuel Production Credit under Section 45Z of the Internal Revenue Code was enacted as part of the Inflation
Reduction Act of 2022 and subsequently amended by the One Big Beautiful Bill Act of 2025 (“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 proposed regulations
remain subject to a 60 day comment period. The final form of these regulations, including future updates to the 45Z‑GREET
model and integration of climate‑smart 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 Inflation Reduction Act 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 June 2025, the EPA proposed RVOs for 2026 and 2027,
setting the implied conventional ethanol levels at 15 billion gallons for 2026 and 2027. The EPA also proposed an increase in
biomass based diesel volumes setting the volumes at 5.61 billion for 2026 and 5.86 billion for 2027. The EPA proposed that
any foreign produced fuel or fuel produced with foreign feedstocks would only generate 50% of the RIN value. In September
2025, the EPA issued a supplemental RVO proposal to reallocate 2023-2025 volumes waived by SREs. They co-proposed
two options: 50% or 100% reallocation. Final 2026-2027 RVOs have not been published as of this filing.
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
34
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. On October 21, 2024, the U.S. Supreme Court agreed to review the various Circuit Court rulings on SREs to
determine the proper venue. In June 2025, the U.S. Supreme Court ruled that legal challenges to EPA SRE 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 SRE litigation. While this ruling provides greater procedural certainty,
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 2025 driving season marking the seventh consecutive year that E15 is able to be sold year-round nationwide.
The EPA has also allowed for the elimination of the One-Pound Waiver for E10 in several Midwestern states beginning with
the 2025 summer driving season, 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.
In October 2019, the White House directed the USDA and EPA to move forward with rulemaking to expand access to
higher blends of biofuels. This includes funding for infrastructure, labeling changes and allowing E15 to be sold through E10
infrastructure. The USDA rolled out the Higher Blend Infrastructure Incentive Program in the summer of 2020, providing
competitive grants to fuel terminals and retailers for installing equipment capable of dispensing higher blends of ethanol and
biodiesel. In December 2021, the USDA announced it would administer another infrastructure grant program. The IRA
provided for an additional $500 million in USDA grants for biofuel infrastructure. On June 26, 2023, the USDA announced
the initial $50 million in awards, and laid out a process for distributing the remaining $450 million, with $90 million being
made available each quarter.
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.
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.
Variability of Commodity Prices
Our business is highly sensitive to commodity price fluctuations, particularly for corn, ethanol, renewable corn oil,
distillers grains, Ultra-High Protein, and natural gas, which are impacted by factors that are outside of our control, including
weather conditions, corn yield, changes in domestic and global ethanol supply and demand, government programs and
policies and the price of crude oil, gasoline and substitute fuels. We use various financial instruments to manage and reduce
our exposure to price variability. For more information about our commodity price risk, refer to Item 7A. - Qualitative and
Quantitative Disclosures About Market Risk, Commodity Price Risk in this report.
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Effects of Inflation
We have experienced inflationary impacts on labor costs, wages, components, equipment, other inputs and services
across our business and inflation and its impact could escalate in future quarters, many of which are beyond our control.
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. Inflation
has and may continue to impact the interest rate environment in which we operate, resulting in a higher cost of capital. Refer
to Item 7A. - Qualitative and Quantitative Disclosures About Market Risk, Commodity Price Risk in this report for additional
information related to interest rate risk.
Critical Accounting Policies and Estimates
The preparation of our consolidated financial statements requires that we use estimates that affect the reported assets,
liabilities, revenue and expense and related disclosures for contingent assets and liabilities. We base our estimates on
experience and assumptions we believe are proper and reasonable. While we regularly evaluate the appropriateness of these
estimates, actual results could differ materially from our estimates. The following accounting policies, in particular, may be
impacted by judgments, assumptions and estimates used in the preparation of our consolidated financial statements.
Derivative Financial Instruments
We use various derivative financial instruments, including exchange-traded futures and exchange-traded and over-the-
counter options contracts, to attempt to minimize risk and the effect of commodity price changes, including but not limited to,
corn, ethanol, natural gas and other agricultural and energy products. We monitor and manage this exposure as part of our
overall risk management policy to reduce the adverse effect market volatility may have on our operating results. We may
hedge these commodities as one way to mitigate risk; however, there may be situations when these hedging activities
themselves result in losses.
By using derivatives to hedge exposures to changes in commodity prices, we are exposed to credit and market risk. Our
exposure to credit risk includes the counterparty’s failure to fulfill its performance obligations under the terms of the
derivative contract. We minimize our credit risk by entering into transactions with high quality counterparties, limiting the
amount of financial exposure it has with each counterparty and monitoring their financial condition. Market risk is the risk
that the value of the financial instrument might be adversely affected by a change in commodity prices or interest rates. We
manage market risk by incorporating parameters to monitor exposure within our risk management strategy, which limits the
types of derivative instruments and strategies we can use and the degree of market risk we can take using derivative
instruments.
Forward contracts are recorded at fair value unless the contracts qualify for, and we elect, normal purchase or sale
exceptions. Changes in fair value are recorded in operating income unless the contracts qualify for, and we elect, cash flow
hedge accounting treatment.
Please refer to Note 10 - Derivative Financial Instruments included in the notes to the audited consolidated financial
statements included herein for further details.
Accounting for Income Taxes
We adopted a new accounting policy related to the recognition, measurement, and presentation of transferable Clean Fuel
Production Credits under Section 45Z of the Internal Revenue Code. In accordance with ASC 740, Accounting for Income
Taxes, accounting guidance states it is most appropriate to apply ASC 740 to nonrefundable transferable tax credits. Under
ASC 740, a company should recognize tax credits when it is “more-likely-than-not” ("MLTN") the underlying qualifying
activity has occurred giving rise to the credit, and the company expects to earn and use or sell the tax credit. If it is uncertain
whether the company will be able to use or sell the credit, a valuation allowance is established against the deferred tax asset.
We have determined that it is MLTN the underlying qualifying activity has occurred to earn the tax credit and therefore,
recognized a tax benefit for gallons produced and sold at certain qualifying plants during the year ended December 31, 2025.
Under this new policy, we recognize the Section 45Z production tax credits as a deferred tax asset, which is treated as a
deferred income tax benefit, net of a valuation allowance to recognize the fair value of the tax credits, and is determined
based on the expected transfer price of the credits. The recognition of the production tax credits is contingent on meeting the
requirements of Section 45Z.
36
Income taxes are accounted for under the asset and liability method in accordance with GAAP. Deferred tax assets and
liabilities are recognized for future tax consequences between existing assets and liabilities and their respective tax basis, and
for net operating loss and tax credit carry-forwards. Deferred tax assets and liabilities are measured using enacted tax rates
expected to be applied to taxable income in years temporary differences are expected to be recovered or settled. The effect of
a tax rate change is recognized in the period that includes the enactment date. The realization of deferred tax assets depends
on the generation of future taxable income during the periods in which temporary differences become deductible.
Management considers scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning
strategies to make this assessment. A valuation allowance is recorded by the company when it is more likely than not that
some portion or all of a deferred tax asset will not be realized. In making such a determination, management considers the
positive and negative evidence to support the need for, or reversal of, a valuation allowance. The weight given to the potential
effects of positive and negative evidence is based on the extent it can be objectively verified.
To account for uncertainty in income taxes, we gauge the likelihood of a tax position based on the technical merits of the
position, perform a subsequent measurement related to the maximum benefit and degree of likelihood, and determine the
benefit to be recognized in the financial statements, if any.
Please refer to Note 15 - Income Taxes included in the notes to the audited consolidated financial statements included
herein for further details.
Recently Issued Accounting Pronouncements
For information related to recent accounting pronouncements, see Note 2 – Summary of Significant Accounting Policies
included in the notes to the audited consolidated financial statements included herein.
Off-Balance Sheet Arrangements
We do not have any off-balance sheet arrangements.
Components of Revenues and Expenses
Revenues. For our ethanol production segment, our revenues are derived primarily from the sale of ethanol, distillers
grains, Ultra-High Protein and renewable corn oil. For our agribusiness and energy services segment, our primary sources of
revenue include sales of distillers grains and renewable corn oil that we market for our ethanol plants, in which we earn a
marketing fee. Our agribusiness and energy services segment also marketed ethanol produced by the plants until April 2025,
when the company executed an agreement for Eco-Energy, LLC to market this production. This segment's revenues also
contain sales of ethanol we marketed for a third-party, which ceased in April of 2025, and Ultra-High Protein we marketed
for a third-party, which ceased in October of 2025, and sales of other commodities purchased in the open market. The vast
majority of our revenues are from forward contracts accounted for as derivatives under ASC 815 as disclosed in the tables
within Note 3 - Revenue and Note 10 - Derivative Financial Instruments included in the notes to the audited consolidated
financial statements included herein. Revenues include net gains or losses from derivatives related to products sold.
Cost of Goods Sold. For our ethanol production segment, cost of goods sold includes materials, direct labor, shipping and
plant overhead costs. Materials include the cost of corn feedstock, natural gas, denaturant and process chemicals. Corn
feedstock costs include gains and losses on related derivative financial instruments not designated as cash flow hedges,
inbound freight charges, inspection costs and transfer costs, as well as reclassifications of gains and losses on cash flow
hedges from accumulated other comprehensive income or loss. Direct labor includes all compensation and related benefits of
personnel involved in ethanol production. Shipping costs incurred by the company, including railcar costs, are also reflected
in cost of goods sold. Plant overhead consists primarily of plant utilities, repairs and maintenance, and outbound freight
charges.
For our agribusiness and energy services segment, purchases of ethanol, distillers grains, renewable corn oil and grain
are the primary component of cost of goods sold. Fair value hedged inventories and forward purchase and sale contracts are
valued at market prices when available or other market quotes adjusted for differences, such as transportation, between the
exchange-traded market and local markets where the terms of the contracts are based. Changes in the market value of grain
inventories, forward purchase and sale contracts, and exchange-traded futures and options contracts are recognized as a
component of cost of goods sold.
Selling, General and Administrative Expenses. Selling, general and administrative expenses are recognized at the
37
operating segment and corporate level. These expenses consist of employee salaries, incentives and benefits; office expenses;
director fees; and professional fees for accounting, legal, consulting and investor relations services. Personnel costs, which
include employee salaries, incentives and benefits, as well as severance and separation costs, are the largest expenditure.
Selling, general and administrative expenses that cannot be allocated to an operating segment are referred to as corporate
activities.
Gain on Sale of Assets. We completed the sale of the ethanol plant located in Rives, Tennessee in September 2025,
resulting in a pretax gain of $35.8 million recorded at the corporate level. We also completed the sale of our 75% interest in
Proventus LLC in May of 2025, resulting in a pretax loss of $4.0 million recorded at the corporate level. We completed the
sale of the terminal located in Birmingham, Alabama in September 2024, resulting in a pretax gain of $30.7 million recorded
at the corporate level. We also completed the sale of the ethanol plant located in Atkinson, Nebraska in September 2023,
resulting in a pretax gain of $4.1 million recorded at the corporate level.
Other Income (Expense). Other income (expense) includes interest earned, interest expense, inclusive of losses from debt
extinguishments of $36.9 million for the year ended December 31, 2025, and other non-operating items including $3.4
million of grants received from the USDA for the year ended December 31, 2023 related to the Biofuel Producer Program.
Income (Loss) from Equity Method Investees, Net of Income Taxes. Income (loss) from equity method investees, net of
income taxes represents our proportional share of earnings from our equity method investees and includes a pretax loss on the
sale of our 50% investment in GP Turnkey Tharaldson of $26.9 million for the year ended December 31, 2025.
Income Tax Benefit (Expense). Income tax benefit (expense) includes clean fuel production tax credits allowable under
the IRA and OBBB. The credits are recognized as a tax benefit in the period in which production occurs, and the product is
sold in a qualifying manner. The tax benefit recognized is determined based on the company's CI score to date and the
expected sales price of the credits.
Results of Operations
We maintained an average utilization rate of approximately 82%, or 94% excluding Fairmont, of capacity during 2025,
compared with 87% of capacity for the prior year, with both years measured using our updated capacity as discussed in Item
1 of this filing. 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 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.
Comparability
The following summarizes various events that affect the comparability of our operating results for the past three years:
• September 2025
Sale of ethanol plant in Rives, Tennessee (or the "Obion Transaction")
• April 2025
Ceasing of a third-party ethanol marketing agreement effective April 1, 2025
• January 2025
Began generating Section 45Z clean fuel production tax credits
• January 2025
Began corporate restructuring and cost savings initiatives lasting throughout 2025
• January 2025
Idling of ethanol plant in Fairmont, Minnesota
• September 2024
Sale of terminal located in Birmingham, Alabama
• September 2023
Sale of ethanol plant located in Atkinson, Nebraska
A discussion regarding our financial condition and results of operations for the year ended December 31, 2024,
compared to the year ended December 31, 2023, can be found under Item 7 in our Annual Report on Form 10-K for the fiscal
year ended December 31, 2024, filed with the SEC on February 7, 2025.
Segment Results
We report the financial and operating performance for the following two operating segments: (1) ethanol production,
38
which includes the production, storage, and transportation of ethanol, distillers grains, Ultra-High Protein and renewable corn
oil 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.
Corporate activities include gain on sale of assets and 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 are as follows (in thousands):
Year Ended December 31,
2025
2024
2023
Revenues
Ethanol production
Revenues from external customers
$
1,900,999 $
2,063,382 $
2,819,986
Intersegment revenues
859
3,707
4,555
Total segment revenues
1,901,858
2,067,089
2,824,541
Agribusiness and energy services
Revenues from external customers
190,681
395,414
475,757
Intersegment revenues
22,662
25,693
25,146
Total segment revenues
213,343
421,107
500,903
Revenues including intersegment activity
2,115,201
2,488,196
3,325,444
Intersegment eliminations
(23,521)
(29,400)
(29,701)
$
2,091,680 $
2,458,796 $
3,295,743
Year Ended December 31,
2025
2024
2023
Cost of goods sold
Ethanol production
$
1,804,279 $
1,983,460 $
2,705,917
Agribusiness and energy services
173,996
374,286
454,776
Intersegment eliminations
(23,521)
(29,400)
(29,701)
$
1,954,754 $
2,328,346 $
3,130,992
39
Year Ended December 31,
2025
2024
2023
Gross margin
Ethanol production (1)(2)
$
97,579 $
83,629 $
118,624
Agribusiness and energy services
39,347
46,821
46,127
$
136,926 $
130,450 $
164,751
Year Ended December 31,
2025
2024
2023
Depreciation and amortization
Ethanol production
$
90,553 $
82,784 $
92,712
Agribusiness and energy services (3)
4,741
2,185
2,360
Corporate activities (4)
3,140
5,618
3,172
$
98,434 $
90,587 $
98,244
Year Ended December 31,
2025
2024
2023
Operating income (loss)
Ethanol production (1)(2)(5)
$
(55,482) $
(40,758) $
(19,958)
Agribusiness and energy services (3)
20,660
28,156
28,100
Corporate activities (4)(6)(7)
(32,426)
(34,857)
(69,720)
$
(67,248) $
(47,459) $
(61,578)
(1)
Ethanol production includes inventory lower of cost or net realizable value adjustments of $1.5 million, $2.1 million, and $2.6 million for the
years ended December 31, 2025, 2024, and 2023, respectively.
(2)
Ethanol production includes margins from a one-time sale of accumulated RINs of $22.6 million for the year ended December 31, 2025.
(3)
Depreciation and amortization for agribusiness and energy services includes impairment of property and equipment of $3.1 million for the year
ended December 31, 2025.
(4)
Depreciation and amortization for corporate activities includes impairment of a research and development technology intangible asset of $3.5
million for the year ended December 31, 2024.
(5)
Ethanol production includes impairment of assets held for sale of $14.6 million for the year ended December 31, 2025.
(6)
Corporate activities includes $16.1 million of restructuring costs for the year ended December 31, 2025, as a result of the company's cost
reduction initiative, including severance related to the departure of its former CEO.
(7)
Corporate activities for the years ended December 31, 2025 and 2024 include a pretax gain on sale of assets, net of $31.5 million and $30.7
million, respectively.
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, net gain on sale of assets, loss on sale of equity method
investment, impairment of assets held for sale, our proportional share of EBITDA adjustments of our equity method
investees, 45Z production tax credits, and other (income) expense related to liability-based warrant expense and the USDA
COVID-19 relief grants. 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.
40
The following table reconciles net loss including noncontrolling interest to adjusted EBITDA (in thousands):
Year Ended December 31,
2025
2024
2023
Net loss
$
(121,000) $
(81,189) $
(76,299)
Interest expense
76,668
33,095
37,703
Income tax expense (benefit), net of equity method income taxes
(52,419)
5,153
(5,617)
Depreciation and amortization (1)
98,434
90,587
98,244
EBITDA
1,683
47,646
54,031
Restructuring costs
24,341
—
—
Gain on sale of assets, net
(31,535)
(30,723)
(5,265)
Impairment of assets held for sale
14,562
—
—
Other (income) expense (2)
2,025
—
(3,440)
45Z production tax credits (3)
54,161
—
—
Loss on sale of equity method investment
26,856
—
—
Proportional share of EBITDA adjustments to equity method investees
1,918
1,792
180
Adjusted EBITDA
$
94,011 $
18,715 $
45,506
(1)
Excludes the amortization of operating lease right-of-use assets and amortization of debt issuance costs.
(2)
Other (income) expense for the year ended December 31, 2025 includes non-cash expense related to the revaluation of liability-based warrants
recorded within other, net on the consolidated statements of operations, while the year ended December 31, 2023 includes grants received from
the USDA related to the Biofuel Producer Program of $3.4 million.
(3)
45Z production tax credits are recorded in income tax benefit on the consolidated statements of operations for the year ended December 31, 2025.
The following table reconciles segment EBITDA to consolidated adjusted EBITDA (in thousands):
Year Ended December 31,
2025
2024
2023
Adjusted EBITDA:
Ethanol production (1)
$
33,247 $
39,645 $
78,561
Agribusiness and energy services
25,661
31,935
31,689
Corporate activities (2)(3)
(57,225)
(23,934)
(56,219)
EBITDA
1,683
47,646
54,031
Restructuring costs
24,341
—
—
Gain on sale of assets, net
(31,535)
(30,723)
(5,265)
Impairment of assets held for sale
14,562
—
—
Other (income) expense (4)
2,025
—
(3,440)
45Z production tax credits (5)
54,161
—
—
Loss on sale of equity method investment
26,856
—
—
Proportional share of EBITDA adjustments to equity method investees
1,918
1,792
180
Adjusted EBITDA
$
94,011 $
18,715 $
45,506
(1)
Ethanol production includes margins from a one-time sale of accumulated RINs of $22.6 million for the year ended December 31, 2025, offset by
41
impairment of assets held for sale of $14.6 million for the year ended December 31, 2025, and an inventory lower of cost or net realizable value
adjustment of $1.5 million, $2.1 million and $2.6 million for the years ended December 31, 2025, 2024 and 2023, respectively.
(2)
Corporate activities includes $16.1 million of restructuring costs for the year ended December 31, 2025 as a result of the company's cost
reduction initiative, including severance related to the departure of its former CEO.
(3)
Corporate activities include a net pretax gain on sale of assets of $31.5 million for the year ended December 31, 2025, and a pretax loss on the
sale of equity method investment of $26.9 million for the same period. Corporate activities include a net pretax gain on sale of assets of $30.7
million for the year ended December 31, 2024.
(4)
Other (income) expense for the year ended December 31, 2025 includes non-cash expense related to the revaluation of liability-based warrants
recorded within other, net on the consolidated statements of operations, while the year ended December 31, 2023 includes grants received from
the USDA related to the Biofuel Producer Program of $3.4 million.
(5)
45Z production tax credits are recorded in income tax benefit on the consolidated statements of operations for the year ended December 31, 2025.
Total assets by segment are as follows (in thousands):
Year Ended December 31,
2025
2024
Total assets (1)
Ethanol production
$
1,133,246 $
1,234,635
Agribusiness and energy services
278,222
412,006
Corporate assets
173,481
143,716
Intersegment eliminations
(6,553)
(8,183)
$
1,578,396 $
1,782,174
(1)
Asset balances by segment exclude intercompany balances.
Year Ended December 31, 2025 compared with the Year Ended December 31, 2024
Consolidated Results
Consolidated revenues decreased $367.1 million in 2025 compared with 2024 primarily as a result of lower ethanol
volumes sold, as well as the company ceasing a third-party ethanol marketing agreement with Tharaldson Ethanol Plant I
LLC effective April 1, 2025.
Net loss increased $39.8 million in 2025 compared with 2024 primarily due to $36.9 million of non-recurring interest
expense related to the junior mezzanine notes extinguished and the convertible notes exchange in 2025, a $26.9 million loss
on sale of equity method investment and non-recurring restructuring costs of $24.3 million, partially offset by the recognition
of $54.2 million of 45Z production tax credits in 2025. Adjusted EBITDA increased $75.3 million in 2025 compared with
2024 primarily due to $54.2 million of year-to-date Section 45Z production tax credit value net of discounts recorded as
income tax benefit in 2025. Interest expense increased $43.6 million in 2025 compared with 2024 driven primarily by the
refinancing and extinguishment of the Junior Notes and the convertible notes exchange in 2025. Income tax benefit,
including income tax benefit from equity method investees, was $52.4 million in 2025 compared to an income tax expense of
$5.2 million in 2024 with the change primarily due to the recognition of $54.2 million of 45Z production tax credits in 2025.
The following discussion provides greater detail about our segment performance.
42
Ethanol Production Segment
Key operating data for our ethanol production segment is as follows:
Year Ended December 31,
2025
2024
Ethanol (thousands of gallons)
764,940
846,226
Distillers grains (thousands of equivalent dried tons)
1,625
1,890
Ultra-High Protein (thousands of tons)
265
248
Renewable corn oil (thousands of pounds)
266,411
290,801
Corn (thousands of bushels)
258,568
289,454
Revenues in our ethanol production segment decreased $165.2 million in 2025 compared with 2024 primarily due to
lower ethanol, distillers grains, and renewable corn oil volumes sold resulting in decreased revenues of $145.1 million, $39.8
million and $11.5 million, respectively, in addition to lower average selling prices of distillers grains resulting in decreased
revenues of $18.9 million, partially offset by higher weighted average selling prices of ethanol and renewable corn oil
volumes sold resulting in increased revenues of $20.2 million and $27.7 million, respectively, as well as $22.6 million related
to a one-time sale of accumulated RINs. Revenues also decreased as a result of hedging activities by $21.7 million.
Cost of goods sold in our ethanol production segment decreased $179.2 million for 2025 compared with 2024 primarily
due to lower corn volumes processed, lower freight costs, lower repair and maintenance costs, lower chemical costs and
hedging activities resulting in decreases of $137.5 million, $80.7 million, $12.6 million, $4.8 million and $1.2 million,
respectively, partially offset by higher ethanol volumes purchased and higher weighted average corn prices resulting in
increased costs of $52.5 million and $17.5 million, respectively.
Operating loss in our ethanol production segment increased $14.7 million in 2025 compared with 2024 primarily due to
impact to margins as outlined above, impairment of assets held for sale of $14.6 million, an increase in depreciation and
amortization expense of $7.8 million as a result of additional assets being placed in service and non-recurring increased
personnel costs as a result of restructuring.
Agribusiness and Energy Services Segment
Revenues in our agribusiness and energy services segment decreased $207.8 million while operating income decreased
$7.5 million in 2025 compared with 2024. The decrease in revenues was primarily a result of the company ceasing a third-
party ethanol marketing agreement with Tharaldson Ethanol Plant I LLC effective April 1, 2025. Operating income decreased
primarily as a result of the impairment of property and equipment of $3.1 million as well as non-recurring increased
personnel costs as a result of restructuring in 2025.
Intersegment Eliminations
Intersegment eliminations of revenues decreased by $5.9 million for 2025 compared with 2024 primarily due to
decreased freight revenue associated with the ethanol production segment as well as 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 a decrease in corporate activities of $2.4 million for 2025 compared with 2024, which
was primarily due to an increase in gain on sale of assets and a decrease in selling, general and administrative expenses as a
result of the company's corporate reorganization and cost reduction initiative, partially offset by non-recurring increased
personnel costs as a result of restructuring.
Income Taxes
We recorded income tax benefit, including income tax benefit from equity method investees of $52.4 million for 2025
compared to an income tax expense of $5.2 million in 2024 with the change primarily due to the recognition in 2025 of 45Z
43
production tax credits.
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 December 31, 2025, we had $182.3 million in cash and cash equivalents and $47.8 million in restricted cash. We also
had $325.0 million available under our committed revolving credit agreement, subject to restrictions or other lending
conditions based specifically on the availability of sufficient eligible collateral to support additional borrowings. Total
corporate liquidity consisting of unrestricted cash and distributable cash from subsidiaries was $138.5 million as of
December 31, 2025. Funds at certain subsidiaries are generally required for their ongoing operational needs and restricted
from distribution. At December 31, 2025, our subsidiaries had approximately $36.8 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.
Net cash provided by (used in) operating activities was $110.9 million in 2025 compared to $(30.0) million in 2024.
Operating activities compared to the prior year were primarily affected by lower receivable and inventory balances due to a
shortened cash conversion cycle resulting from the marketing agreement with Eco-Energy, LLC. This improvement was
partially offset by a higher net loss compared to the prior year. Net cash provided by (used in) investing activities was $162.1
million in 2025 compared to $(62.1) million in 2024 primarily due to increases in proceeds from sale of assets and equity
method investment, partially offset by decreases in capital expenditures. Net cash used in financing activities was $252.3
million in 2025 compared to $77.4 million in 2024 primarily due to the repayment of the Junior Notes, payments for
repurchase of common stock and higher net payments on the revolver, partially offset by the prior period extinguishment of
non-controlling interest when compared to 2024.
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 $37.2 million in 2025, related to various capital projects. The current projected
estimate for capital spending related to maintenance, environmental, health and safety is approximately $15 million to $25
million in 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 growth projects during
2026.
The company financed the CCS projects at its three Nebraska plants. The company anticipates payments to begin in
2026 and projects annualized payments of $17.1 million.
The company recognized $54.2 million of income tax benefit related to 45Z production tax credits during the year ended
December 31, 2025. Based on current production outlook and eligible gallons the company expects to generate at least $188
million of 45Z-related of adjusted EBITDA, net of discounts and applicable operating expenses, for the year ended December
31, 2026. This is subject to change based on actual production volumes and CI factors at eligible plants.
During the year ended December 31, 2025, the company recognized a loss on debt extinguishment of $36.9 million,
which was recorded within interest expense on the consolidated statements of operations. Further, on October 27, 2025 the
company completed a $200.0 million convertible note exchange resulting in $170.0 million of the 2.25% senior notes due
2027 being extinguished. The interest rate on the new convertible notes due 2030 is 5.25%. When considering the
extinguishment of the Junior Notes, the increased interest rate on convertible notes, the increased amount of outstanding
convertible notes and anticipated interest expense related to the carbon equipment financing, the company expects annualized
interest expense of approximately $30 to $35 million for the year ended December 31, 2026. This estimate is subject to
change based on actual working capital revolver usage and market interest rates in future periods.
44
Our business is highly sensitive to the price of commodities, particularly for corn, ethanol, distillers grains (including
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.
Our board of directors 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. On October 27, 2025, in conjunction with the privately negotiated
exchange and subscription agreements for the 2030 Notes, the company repurchased 2.9 million shares of its common stock
for a total of $30.0 million under the repurchase program. No other repurchase was made during 2025. We did not repurchase
any common stock in 2024 or 2023. To date, we have repurchased approximately 10.3 million shares of common stock for
approximately $122.8 million under the program. At February 10, 2026, $77.2 million in share repurchase authorization
remained.
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, expand our business or acquire businesses.
Debt
We were in compliance with our debt covenants at December 31, 2025. 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.
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”). $200 million in aggregate principal amount of
the 2030 Notes is now outstanding, and $60 million in aggregate principal amount of the 2027 Notes remains outstanding
with existing terms unchanged. The 2030 Notes will 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 notes will be general senior, 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 December 31, 2025, the outstanding principal balances on the remaining 2027 Notes and the 2030 Notes was
$60.0 million and $200.0 million, respectively.
On May 7, 2025, we entered into a secured $30 million revolving credit facility with Ancora Alternatives LLC, that gave
45
us additional flexibility in order to continue the implementation of our strategic plan. The facility matured on July 30, 2025.
The facility bore interest at 10% on borrowings and had a 0.5% fee on the unused balance. Interest and fees were due on the
5th of each month. Also executed as part of the credit facility, the company issued 1,504,140 stock warrants at a strike price
of $0.01 per share. The warrants had a ten year exercise period.
Ethanol Production Segment
On September 25, 2025, proceeds from the Obion Transaction were used to fully retire the Junior Notes. The Junior
Notes were originally issued on February 9, 2021, by Green Plains SPE LLC, a wholly-owned special purpose subsidiary and
parent of Green Plains Obion and Green Plains Mount Vernon for $125.0 million due February 2026 with BlackRock. The
Junior Notes were secured by a pledge of the membership interests in and the real property owned by Green Plains Obion and
Green Plains Mount Vernon. On May 7, 2025 the Junior Notes were amended to give the company additional flexibility in
order to continue the implementation of our strategic plan, which extended the maturity date from February 9, 2026 to May
15, 2026, with an amendment fee of 2.0% added to the principal balance of the Junior Notes, payable at the maturity date.
Further, the strike price of warrants previously issued in conjunction with the Junior Notes was revised from $22.00 to $0.01
and the maturity date extended from April 28, 2026 to December 31, 2029. As of July 31, 2025, the Junior Notes also were
secured by a pledge of the membership interests in, the assets and the real property owned by Green Plains Madison LLC,
Green Plains Superior LLC, Green Plains Fairmont LLC, Green Plains Otter Tail LLC, Green Plains Wood River and Green
Plains York LLC, as well as the assets and membership interests of Fluid Quip Mechanical, LLC.
On August 10, 2025, the company amended and restated the indenture covering the Junior Notes with BlackRock to
extend the maturity date to September 15, 2026, with an amendment fee of 2.5% added to the principal balance of the Junior
Notes, payable at the maturity date. The interest rate increased by 0.5% after the amendment, and by an additional 0.5% each
quarter on each scheduled interest payment date. In addition to assets and equity securities pledged, the Junior Notes were
then also secured by the assets and the real property owned by Green Plains Central City LLC. The amendment added certain
financial covenant requirements, including restrictions on additional debt and certain transfer of assets. Also as part of the
amendment, the company executed a subscription agreement with certain funds and accounts under management by
BlackRock pursuant to which the company agreed to issue, and certain funds and accounts under management by BlackRock
purchased, 3,250,000 stock warrants at a strike price of $0.01 per share with a ten year exercise period. The amendment also
included the right for such funds and accounts to exchange up to 750,000 warrants for a pro rata share of $6 million of
outstanding principal of Junior Notes. The subscription agreement obligated the company to register for resale the shares of
common stock underlying warrants issued to BlackRock.
Green Plains Shenandoah, a wholly-owned subsidiary, has a $75.0 million secured loan agreement, which matures on
September 1, 2035. During the second quarter of 2024, the agreement was modified to remove the Wood River facility from
the assets considered to be secured under the loan agreement and Green Plains Wood River was removed as a counterparty to
the loan agreement. At December 31, 2025, the outstanding principal balance was $70.1 million on the loan and the interest
rate was 6.52%.
On and after July 24, 2023, Green Plains York Capture Company LLC, a wholly-owned subsidiary of the company,
entered into a series of agreements with Tallgrass High Plains Carbon Storage, LLC and its affiliates to finance, construct and
operate carbon capture, transportation and sequestration assets associated with the Company’s York, Nebraska ethanol
facility. Under the agreements, Green Plains York Capture Company LLC is 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. As of
December 31, 2025, this project has met criteria for substantial completion and is classified as debt. The total estimated value
of this debt recorded on the balance sheet is $34.5 million. Repayments commenced in January 2026. This debt is secured by
substantially all real and personal property interests associated with the Green Plains York Capture Company LLC. Green
Plains Inc. further supports the obligation through a Parent Guaranty, under which it unconditionally guarantees Green Plains
York Capture Company LLC’s performance and payment obligations. Green Plains York Capture Company LLC may pre-
repay the obligation early by providing Tallgrass at least ninety days prior written notice and remitting the prepayment, which
represents the amount required for Tallgrass to achieve its contracted 9% pretax, unlevered internal rate of return on its
investments.
The total spend related to the other two Nebraska CCS construction projects has been recorded within carbon equipment
liabilities on the consolidated balance sheets. While fully operational as of December 31, 2025, these two projects did not
reach substantial completion until January of 2026. The amounts presented as carbon equipment liabilities as of
December 31, 2025 will be reclassified and presented as debt on the consolidated balance sheets in January of 2026.
46
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 have total senior secured revolving
commitments of $350.0 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. The facility matures in March 2027. 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 December 31, 2025, the
outstanding principal balance was $25.0 million on the facility and the interest rate was 7.48%.
Green Plains Commodity Management has an uncommitted secured revolving credit facility to finance margins related
to its hedging programs, which is secured by cash and securities held in its brokerage accounts. During the first quarter of
2023, this revolving credit facility was extended five years to mature on April 30, 2028. On June 18, 2025, the credit facility
was amended, reducing the $40.0 million borrowing limit to $20.0 million. Advances are subject to variable interest rates
equal to SOFR plus 1.75%. At December 31, 2025, the outstanding principal balance was $8.6 million on the facility and the
interest rate was 5.46%.
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 December 31, 2025.
Refer to Note 11 – Debt included in the notes to the audited consolidated financial statements included herein for more
information about our debt.
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 December 31, 2025 totaled $72.3 million. As of December 31, 2025, we had
contracted future purchases of grain, ethanol, distillers grains, and natural gas valued at approximately $202.2 million, future
commitments for storage and transportation valued at approximately $31.4 million, and accumulated commitments related to
the construction of carbon capture and sequestration equipment at our three Nebraska plants of $104.2 million. Refer to Note
16 – Commitments and Contingencies included in the notes to consolidated financial statements for more information.
Item 7A. Qualitative and Quantitative Disclosures About Market Risk.
We use various financial instruments to manage and reduce our exposure to various market risks, including changes in
commodity prices and interest rates. We conduct the majority of our business in U.S. dollars and are not currently exposed to
material foreign currency risk.
Interest Rate Risk
We are exposed to interest rate risk through our loans which bear interest at variable rates. Interest rates on our variable-
rate debt are based on the market rate for the lender’s prime rate or SOFR. At December 31, 2025, we had $408.1 million in
debt, $33.6 million of which had variable interest rates. A 10% increase in interest rates would affect our interest cost by
approximately $0.3 million per year.
Refer to Note 11 – Debt included in the notes to the audited consolidated financial statements included herein for more
information about our debt.
47
Commodity Price Risk
Our business is highly sensitive to commodity price risk, particularly for ethanol, corn, distillers grains (including Ultra-
High Protein), renewable corn oil and natural gas. Ethanol prices are sensitive to world crude oil supply and demand, the
price of crude oil, gasoline, corn, the price of substitute fuels, refining capacity and utilization, government regulation and
consumer demand for alternative fuels. Corn prices are affected by weather conditions, yield, changes in domestic and global
supply and demand, and government programs and policies. Distillers grains and Ultra-High Protein prices are impacted by
livestock numbers on feed, prices for feed alternatives and supply, which is associated with ethanol plant production.
Renewable corn oil prices are impacted by prices for renewable diesel fuel, diesel fuel and competing feedstocks. Natural gas
prices are influenced by severe weather in the summer and winter and hurricanes in the spring, summer and fall. Other factors
include North American energy exploration and production, and the amount of natural gas in underground storage during
injection and withdrawal seasons.
To reduce the risk associated with fluctuations in the price of ethanol, corn, distillers grains, Ultra-High Protein,
renewable corn oil and natural gas, at times we use forward fixed-price physical contracts and derivative financial
instruments, such as futures and options executed on the Chicago Board of Trade, the New York Mercantile Exchange and the
Chicago Mercantile Exchange. We focus on locking in favorable operating margins, when available, using a model that
continually monitors market prices for corn, natural gas and other inputs relative to the price for ethanol and distillers grains
at each of our production facilities. We create offsetting positions using a combination of forward fixed-price purchases, sales
contracts and derivative financial instruments. As a result, we frequently have gains on derivative financial instruments that
are offset by losses on forward fixed-price physical contracts or inventories and vice versa. Our results are impacted by a
mismatch of gains or losses associated with the derivative instrument during a reporting period when the physical commodity
purchases or sale has not yet occurred. For the year ended December 31, 2025, revenues included net losses of $12.9 million
and cost of goods sold included net losses of $6.1 million associated with derivative instruments.
Ethanol Production Segment
In the ethanol production segment, net gains and losses from settled derivative instruments are offset by physical
commodity purchases or sales to achieve the intended operating margins. To reduce commodity price risk caused by market
fluctuations, we enter into exchange-traded futures and options contracts that serve as economic hedges.
Our exposure to market risk, which includes the impact of our risk management activities resulting from our fixed-price
purchase and sale contracts and derivatives, is based on the estimated net income effect resulting from a hypothetical 10%
change in price for the next 12 months starting on December 31, 2025, are as follows (in thousands):
Commodity
Estimated Total Volume
Requirements for the
Next 12 Months (1)
Unit of
Measure
Net Income Effect of
Approximate 10%
Change in Price
Ethanol
730,000
Gallons
$81,682
Corn
246,000
Bushels
$80,648
Distillers grains (2)
1,710
Tons (3)
$16,902
Renewable corn oil
254,000
Pounds
$9,362
Natural gas
19,900
MmBTU
$4,360
(1)
Estimated volumes assume production at full capacity, excluding the idled Fairmont, Minnesota plant.
(2)
Includes Ultra-High Protein
(3)
Distillers grains quantities are stated on an equivalent dried ton basis.
Agribusiness and Energy Services Segment
In the agribusiness and energy services segment, our physical purchase and sale contracts and derivatives are marked to
market. Our inventories are carried at the lower of cost or net realizable value, except fair-value hedged inventories. To
reduce commodity price risk caused by market fluctuations for purchase and sale commitments of grain and grain held in
inventory, we enter into exchange-traded futures and options contracts that serve as economic hedges.
48
The market value of exchange-traded futures and options used for hedging are highly correlated with the underlying
market value of grain inventories and related purchase and sale contracts for grain. The less correlated portion of inventory
and purchase and sale contract market values, known as basis, is much less volatile than the overall market value of
exchange-traded futures and tends to follow historical patterns. We manage this less volatile risk by constantly monitoring
our position relative to the price changes in the market. Inventory values are affected by the month-to-month spread in the
futures markets. These spreads are also less volatile than the overall market value of our inventory and tend to follow
historical patterns, but cannot be mitigated directly. Our accounting policy for futures and options, as well as the underlying
inventory held for sale and purchase and sale contracts, is to reflect their current market values and include gains and losses
in the consolidated statement of operations.
Item 8. Financial Statements and Supplementary Data.
The required consolidated financial statements and accompanying notes are listed in Part IV, Item 15.
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.
None.
Item 9A. Controls and Procedures.
Evaluation of Disclosure Controls and Procedures
We maintain disclosure controls and procedures designed to ensure information that must be disclosed in the reports we
file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in
the SEC’s rules and forms, and that such information is accumulated and communicated to management, as appropriate, to
allow timely decisions regarding required financial disclosure. In designing and evaluating the disclosure controls and
procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide
only reasonable assurance of achieving the desired control objectives. Management is required to apply its judgment in
evaluating the cost-benefit relationship of possible controls and procedures.
Under the supervision of and participation of our chief executive officer and chief financial officer, management carried
out an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures as of
December 31, 2025, as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act and concluded that our disclosure
controls and procedures were effective.
Management’s Annual Report on Internal Control over Financial Reporting
Management is responsible for establishing and maintaining effective internal control over financial reporting as defined
in Rule 13a-15(f) of the Exchange Act. Our internal control system is designed to provide reasonable assurance regarding the
reliability of financial reporting and the preparation of financial statements in accordance with GAAP.
Under the supervision and participation of our chief executive officer and chief financial officer, management assessed
the design and operating effectiveness of our internal control over financial reporting as of December 31, 2025, based on the
Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway
Commission. Based on this assessment, management concluded that our internal control over financial reporting was
effective as of December 31, 2025.
The effectiveness of the company’s internal control over financial reporting as of December 31, 2025, has been audited
by KPMG LLP, an independent registered public accounting firm, as stated in their report, which is included herein.
Changes in Internal Control over Financial Reporting
Management is responsible for establishing and maintaining effective internal control over financial reporting to provide
reasonable assurance regarding the reliability of our financial reporting and the preparation of our consolidated financial
statements for external purposes in accordance with GAAP. We have not identified any changes in our internal control over
financial reporting that occurred during the quarter ended December 31, 2025, that have materially affected, or are reasonably
likely to materially affect, our internal control over financial reporting.
49
Report of Independent Registered Public Accounting Firm
To the Stockholders and Board of Directors
Green Plains Inc.:
Opinion on Internal Control Over Financial Reporting
We have audited Green Plains Inc. and subsidiaries' (the Company) internal control over financial reporting as of
December 31, 2025, based on criteria established in Internal Control – Integrated Framework (2013) issued by the
Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, the Company maintained, in all
material respects, effective internal control over financial reporting as of December 31, 2025, based on criteria established in
Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway
Commission.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States)
(PCAOB), the consolidated balance sheets of the Company as of December 31, 2025 and 2024, the related consolidated
statements of operations, comprehensive loss, stockholders’ equity, and cash flows for each of the years in the three-year
period ended December 31, 2025, and the related notes (collectively, the consolidated financial statements), and our report
dated February 10, 2026 expressed an unqualified opinion on those consolidated financial statements.
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
Annual 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 of internal control over financial reporting included obtaining an understanding of internal
control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and
operating effectiveness of internal control based on the assessed risk. Our audit also included 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/ KPMG LLP
Omaha, Nebraska
February 10, 2026
50
Item 9B. Other Information.
During the year ended December 31, 2025, no director or officer of the company adopted, modified or terminated a
"Rule 10b5-1 trading arrangement" or "non-Rule 10b5-1 trading arrangement," as each term is defined in Item 408(a) of
Regulation S-K.
Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections.
Not applicable.
PART III
Item 10. Directors, Executive Officers and Corporate Governance.
Information in our Proxy Statement for the 2026 Annual Meeting of Stockholders (“Proxy Statement”) under “Corporate
Governance,” “Proposal 1 – Election of Directors,” “Executive Officers,” and under the subheading “Executive
Compensation—Compensation Disclosure and Analysis—Compensation Policies and Procedures—Insider Trading Policy” is
incorporated by reference.
We have adopted a code of ethics that applies to our chief executive officer, chief financial officer and all other senior
financial officers. Our code of ethics is available on our website at www.gpreinc.com in the “Investors and Media –
Governance” section. Amendments or waivers are disclosed within five business days following its adoption.
Item 11. Executive Compensation.
Information included in the Proxy Statement under “Corporate Governance - Compensation of Directors” and
“Executive Compensation” other than the “Pay vs. Performance Comparison” subheading is incorporated by reference.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.
Information in the Proxy Statement under “Security Ownership of Certain Beneficial Owners and Management” and
“Executive Compensation” other than the “Pay vs. Performance Comparison” subheading is incorporated by reference.
Item 13. Certain Relationships and Related Transactions, and Director Independence.
Information in the Proxy Statement under "Corporate Governance" and “Transactions with Related Persons, Promoters
and Certain Control Persons” is incorporated by reference.
Item 14. Principal Accounting Fees and Services.
Information in the Proxy Statement under “Independence of Auditors” and "Auditors' Fees" is incorporated by reference.
51
PART IV
Item 15. Exhibits, Financial Statement Schedules.
(1) Financial Statements. The following consolidated financial statements and notes are filed as part of this annual
report on Form 10-K.
Page
Report of Independent Registered Public Accounting Firm
F-1
Auditor Name: KPMG LLP
Auditor Location: Omaha, NE
Auditor Firm ID: 185
Consolidated Balance Sheets as of December 31, 2025 and 2024
F-3
Consolidated Statements of Operations for the years ended December 31, 2025, 2024 and 2023
F-4
Consolidated Statements of Comprehensive Loss for the years ended December 31, 2025, 2024 and 2023
F-5
Consolidated Statements of Stockholders’ Equity for the years ended December 31, 2025, 2024 and 2023
F-6
Consolidated Statements of Cash Flows for the years ended December 31, 2025, 2024 and 2023
F-7
Notes to Consolidated Financial Statements
F-9
(2) Financial Statement Schedules. All schedules have been omitted because they are not applicable or the required
information is included in the consolidated financial statements or notes thereto.
(3) Exhibits. The following exhibits are incorporated by reference, filed or furnished as part of this annual report on
Form 10-K.
Exhibit Index
Exhibit No. Description of Exhibit
**2.1(a)
Asset Purchase Agreement among Hereford Ethanol Partners, L.P. and Green Plains Hereford LLC, dated
December 11, 2020 (incorporated herein by reference to Exhibit 2.9(a) to the company's Annual Report on
Form 10-K filed on February 16, 2021)
2.1(b)
Asset Purchase Agreement, dated December 14, 2020, by and among Green Plains LP, Green Plains
Holdings LLC, Green Plains Operating Company LLC, Green Plains Ethanol Storage LLC, Green Plains
Logistics LLC, Green Plains Inc., Green Plains Trade Group LLC and Green Plains Hereford LLC.
(incorporated herein by reference to Exhibit 2.2 to the company's Current Report on Form 8-K filed on
December 15, 2020).
**2.2
Agreement and Plan of Merger, dated September 16, 2023, by and among Green Plains Inc., GPLP Holdings
Inc., GPLP Merger Sub LLC, Green Plains Holdings LLC and Green Plains Partners LP. (incorporated
herein by reference to Exhibit 2.1 to the company's Current Report on Form 8-K filed September 18, 2023).
**2.3(a)
Asset Purchase Agreement, dated August 22, 2025, by and among Green Plains Obion LLC and POET
Biorefining - Obion, LLC. (incorporated herein by reference to Exhibit 2.1 to the company's Current Report
on Form 8-K filed on August 27, 2025)
**2.3(b)
First Amendment to Asset Purchase Agreement, dated September 25, 2025 by and between Green Plains
Obion LLC and POET Biorefining - Obion, LLC (incorporated herein by reference to Exhibit 2.1(b) to the
company's Quarterly Report on Form 10-Q filed on November 5, 2025)
3.1(a)
Second Amended and Restated Articles of Incorporation of the company (incorporated herein by reference to
Exhibit 3.1 of the company’s Current Report on Form 8-K filed October 15, 2008)
3.1(b)
Articles of Amendment to Second Amended and Restated Articles of Incorporation of Green Plains
Renewable Energy, Inc. (incorporated herein by reference to Exhibit 3.1 of the company’s Current Report on
Form 8-K filed May 9, 2011)
52
3.1(c)
Second Articles of Amendment to Second Amended and Restated Articles of Incorporation of Green Plains
Renewable Energy, Inc. (incorporated herein by reference to Exhibit 3.1 to the company’s Current Report on
Form 8-K filed May 16, 2014)
3.1(d)
Third Articles of Amendment to Second Amended and Restated Articles of Incorporation of Green Plains,
Inc. (incorporated herein by reference to Exhibit 3.1 to the company's Current Report on Form 8-K filed on
May 6, 2022)
3.2
Fifth Amended and Restated Bylaws of Green Plains Inc., dated November 14, 2022 (incorporated herein by
reference to Exhibit 3.1 to the company’s Current Report on Form 8-K filed on November 16, 2022)
4.1(a)
Indenture, dated March 1, 2021, between Green Plains Inc. and Wilmington Trust, National Association, as
trustee (incorporated herein by reference to Exhibit 4.1 to the company’s Current Report on Form 8-K dated
March 1, 2021)
4.1(b)
First Supplemental Indenture relating to the 2.25% Convertible Senior Notes due 2027, dated as of March 1,
2021, between Green Plains Inc. and Wilmington Trust, National Association, including the form of Global
Note attached as Exhibit A thereto (incorporated herein by reference to Exhibit 4.2 to the company’s Current
Report on Form 8-K dated March 1, 2021)
4.1(c)
Form of Global Note representing 2.25% Convertible Senior Notes due 2027 (included as a part of Exhibit
4.3(b)).
4.2
Indenture relating to the 4.00% Convertible Senior Notes due 2024, dated as of June 21, 2019, between
Green Plains Inc. and Wilmington Trust, National Association, including the form of Global Note attached as
Exhibit A thereto (incorporated herein by reference to Exhibit 4.1 of the company’s Current Report on Form
8-K filed on June 21, 2019)
4.3
Description of Securities Registered Under Section 12 of the Exchange Act (incorporated herein by reference
to Exhibit 4.1 of the company’s Quarterly Report on Form 10-Q filed on May 3, 2024)
**4.4(a)
Indenture, dated October 27, 2025, between Green Plains Inc. and Wilmington Trust, National Association,
as trustee. (incorporated herein by reference to Exhibit 4.1 to the company's Current Report on Form 8-K
filed on October 28, 2025)
**4.4(b)
Form of Global Note representing 5.25% Convertible Senior Notes due 2030 (included as a part of Exhibit
4.4(a) of this Form 10-K). (incorporated herein by reference to Exhibit 4.1 to the company's Current Report
on Form 8-K filed on October 28, 2025)
10.1
Form of Indemnification Agreement (incorporated herein by reference to Exhibit 10.53 of the company’s
Registration Statement on Form S-4/A filed August 1, 2008)
*10.2(a)
Employment Agreement by and between Green Plains Renewable Energy, Inc. and Todd Becker dated May
7, 2008 (incorporated herein by reference to Exhibit 10.54 of the company’s Registration Statement on Form
S-4/A filed August 1, 2008)
*10.2(b)
Amendment No. 1 to Employment Agreement by and between Green Plains Renewable Energy, Inc. and
Todd Becker, dated December 18, 2009. (incorporated herein by reference to Exhibit 10.7(b) of the
company’s Annual Report on Form 10-K filed February 24, 2010)
*10.2(c)
Amendment No. 2 to Employment Agreement by and between Green Plains, Inc. and Todd Becker, dated
March 27, 2018 (incorporated herein by reference to Exhibit 10.52 of the company’s Quarterly Report on
Form 10-Q filed on May 7, 2018)
*10.2(d)
Executive Change in Control Severance Plan Participation Letter by and between Green Plains Inc. and Todd
A. Becker, dated August 2, 2023 (incorporated herein by reference to Exhibit 10.3 to the company's
Quarterly Report on Form 10-Q filed on August 4, 2023)
*10.2(e)
Amendment No. 3 to Employment Agreement by and between Green Plains Inc. and Todd Becker dated
December 1, 2024 (incorporated herein by reference to Exhibit 10.28 to the company's Annual Report on
Form 10-K filed on February 7, 2025)
*10.2(f)
Executive Transition and Separation Agreement by and between Green Plains Inc. and Todd Becker effective
March 1, 2025 (incorporated herein by reference to Exhibit 10.1 to the company's Current Report on Form 8-
K filed on February 28, 2025)
*10.3(a)
2019 Equity Incentive Plan (incorporated herein by reference to Appendix A of the company’s Definitive
Proxy Statement filed March 28, 2019)
53
*10.3(b)
Amendment No. 1 to the 2019 Equity Incentive Plan (incorporated herein by reference to Appendix A of the
company’s Definitive Proxy Statement filed March 26, 2020)
*10.3(c)
Green Plains Inc. Restricted Stock Agreement for 2019 Equity Incentive Plan (incorporated herein by
reference to Exhibit 10.5(c) to the company's Annual Report on Form 10-K filed on February 9, 2024)
*10.3(d)
Green Plains Inc. Performance Share Unit Agreement for 2019 Equity Incentive Plan (incorporated herein by
reference to Exhibit 10.5(d) to the company's Annual Report on Form 10-K filed on February 9, 2024)
*10.4
Umbrella Short-Term Incentive Plan (incorporated herein by reference to Appendix A of the company’s
Proxy Statement filed April 3, 2014)
*10.5(a)
Employment Agreement by and between Green Plains Renewable Energy, Inc. and Patrich Simpkins dated
April 1, 2012 (incorporated herein by reference to Exhibit 10.2 of the company’s Quarterly Report on Form
10-Q filed May 1, 2014)
*10.5(b)
Executive Change in Control Severance Plan Participation Letter by and between Green Plains Inc. and
Patrich Simpkins, dated August 2, 2023 (incorporated herein by reference to Exhibit 10.3 to the company's
Quarterly Report on Form 10-Q filed on August 4, 2023)
*10.6(a)
Employment Agreement by and between Green Plains Inc. and Michelle S. Mapes dated February 3, 2020
(incorporated herein by reference to Exhibit 10.12 of the company’s Annual Report on Form 10-K filed
February 20, 2020)
*10.6(b)
Executive Change in Control Severance Plan Participation Letter by and between Green Plains Inc. and
Michelle Mapes, dated August 2, 2023 (incorporated herein by reference to Exhibit 10.3 to the company's
Quarterly Report on Form 10-Q filed on August 4, 2023)
*10.6(c)
Amendment No. 1 to Employment Agreement by and between Green Plains Inc. and Michelle Mapes
effective February 27, 2025 (incorporated herein by reference to Exhibit 10.2 to the company's Current
Report on Form 8-K/A filed on March 4, 2025)
10.7(a)
Revolving Credit Facility, dated as of April 30, 2018, by and among Green Plains Commodity Management
LLC and Macquarie Bank Limited (incorporated herein by reference to Exhibit 10.4 to the company’s
Quarterly Report on Form 10-Q dated May 7, 2018)
10.7(b)
Amendment to Revolving Credit Facility, dated as of June 18, 2019, by and among Green Plains Commodity
Management LLC and Macquarie Bank Limited (incorporated herein by reference to Exhibit 10.24(b) of the
company’s Annual Report on Form 10-K filed February 20, 2020)
10.7(c)
Second Amendment to Revolving Credit Facility, dated as of November 24, 2021, by and among Green
Plains Commodity Management LLC, Macquarie Bank Limited and Macquarie Futures USA LLC
(incorporated herein by reference to Exhibit 10.1 of the company’s Quarterly Report on Form 10-Q filed
May 4, 2023)
10.7(d)
Third Amendment to Revolving Credit Facility, dated as of February 20, 2022, by and among Green Plains
Commodity Management LLC, Macquarie Bank Limited and Macquarie Futures USA LLC (incorporated
herein by reference to Exhibit 10.2 of the company’s Quarterly Report on Form 10-Q filed May 4, 2023)
10.7(e)
Fourth Amendment to Revolving Credit Facility, dated as of June 18, 2025, by and among Green Plains
Commodity Management LLC, Macquarie Bank Limited and Macquarie Futures USA LLC (incorporated
herein by reference to Exhibit 10.9 to the company's Quarterly Report on Form 10-Q filed on August 11,
2025)
10.8(a)
Loan Agreement dated September 3, 2020 by and among Green Plains Wood River LLC and Green Plains
Shenandoah LLC, as the Borrowers, and MetLife Real Estate Lending LLC, as the Lender (incorporated
herein by reference to Exhibit 10.1 to the company’s Current Report on Form 8-K filed on September 8,
2020)
10.8(b)
Delayed Draw Term Promissory Note dated September 3, 2020 by and among Green Plains Wood River
LLC and Green Plains Shenandoah LLC, as the Borrowers, and MetLife Real Estate Lending LLC, as the
Lender (incorporated herein by reference to Exhibit 10.2 to the company’s Current Report on Form 8-K filed
on September 8, 2020)
10.8(c)
Loan Guaranty Agreement dated September 3, 2020 by and among Green Plains Inc, as the Guarantor, and
MetLife Real Estate Lending LLC, as the Lender (incorporated herein by reference to Exhibit 10.3 to the
company’s Current Report on Form 8-K filed on September 8, 2020)
54
10.8(d)
Deed of Trust, Security Agreement, Assignment of Leases and Rents and Fixture Filing dated September 3,
2020 by and among Green Plains Wood River LLC, as the Trustor, and MetLife Real Estate Lending LLC, as
the Beneficiary (incorporated herein by reference to Exhibit 10.4 to the company’s Current Report on Form
8-K filed on September 8, 2020)
10.8(e)
Mortgage, Security Agreement, Assignment of Leases and Rents and Fixture Filing dated September 3, 2020
by and among Green Plains Shenandoah LLC, as the Borrower, and MetLife Real Estate Lending LLC, as
the Lender (incorporated herein by reference to Exhibit 10.5 to the company’s Current Report on Form 8-K
filed on September 8, 2020)
10.8(f)
Modification to the Loan Agreement, dated May 24, 2024, by and among Green Plains Wood River LLC,
and Green Plains Shenandoah, LLC, as the Borrowers, and MetLife Real Estate Lending LLC, as the Lender
(incorporated herein by reference to Exhibit 10.1 of the company’s Quarterly Report on Form 10-Q filed
August 6, 2024)
**10.9(a)
Note Purchase Agreement dated February 9, 2021 by and among Green Plains SPE LLC, as the Issuer, Green
Plains Inc., as Guarantor, and Purchasers signatory thereto (incorporated herein by reference to Exhibit 10.1
to the company’s Current Report on Form 8-K filed on February 12, 2021)
**10.9(b)
Pledge and Security Agreement dated February 9, 2021 by and among Green Plains SPE LLC, as the
Pledgor, in favor of Wilmington Trust, National Association, as Trustee (incorporated herein by reference to
Exhibit 10.2 to the company’s Current Report on Form 8-K filed on February 12, 2021)
**10.9(c)
Indenture dated February 9, 2021 by Green Plains SPE LLC, as Issuer, Green Plains Inc., as Guarantor and
Wilmington Trust, National Association, as Trustee. (incorporated herein by reference to Exhibit 10.3 to the
company’s Current Report on Form 8-K filed on February 12, 2021)
10.9(d)
First Priority Mortgage, Assignment of Leases and Rents, Security Agreement and Financing Statement from
Green Plains Mount Vernon LLC, as Mortgagor and Wilmington Trust, National Association, as Mortgagee.
(incorporated herein by reference to Exhibit 10.4 to the company’s Current Report on Form 8-K filed on
February 12, 2021)
10.9(e)
First Priority Deed of Trust, Assignment of Leases and Rents, Security Agreement and Financing Statement
from Green Plains Obion LLC, as Mortgagor and Wilmington Trust, National Association, as Mortgagee.
(incorporated herein by reference to Exhibit 10.5 to the company’s Current Report on Form 8-K filed on
February 12, 2021)
10.9(f)
First Supplemental Indenture, dated May 7, 2025, related to Note Purchase Agreement dated February 9,
2021, by Green Plains SPE LLC, as Issuer, Green Plains Inc., as Guarantor and Wilmington Trust, National
Association, as Trustee (incorporated herein by reference to Exhibit 10.8 to the company's Quarterly Report
on Form 10-Q filed on May 8, 2025)
10.9(g)
Guarantee Agreement, dated as of May 7, 2025, between Green Plains SPE LLC, as Issuer, Green Plains
Inc., as Guarantor, each of the entities listed on Exhibit A as Additional Guarantors, and Wilmington Trust,
National Association, as Trustee, under the Indenture, dated as of February 9, 2021, as amended by
Amendment No. 1 dated May 13, 2022 and as supplemented by the first supplemental indenture, dated May
7, 2025 (incorporated herein by reference to Exhibit 10.9 to the company's Quarterly Report on Form 10-Q
filed on May 8, 2025)
10.9(h)
Second Amended and Restated Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated
May 7, 2025, by and between Green Plains Inc. and BlackRock Global Allocation Fund, Inc. (incorporated
herein by reference to Exhibit 10.10(a) to the company's Quarterly Report on Form 10-Q filed on May 8,
2025)
10.9(i)
Second Amended and Restated Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated
May 7, 2025, by and between Green Plains Inc. and BlackRock Global Allocation Collective Fund
(incorporated herein by reference to Exhibit 10.10(b) to the company's Quarterly Report on Form 10-Q filed
on May 8, 2025)
10.9(j)
Second Amended and Restated Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated
May 7, 2025, by and between Green Plains Inc. and BlackRock Total Return Bond Fund (incorporated herein
by reference to Exhibit 10.10(c) to the company's Quarterly Report on Form 10-Q filed on May 8, 2025)
55
10.9(k)
Second Amended and Restated Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated
May 7, 2025, by and between Green Plains Inc. and Strategic Income Opportunities Bond Fund
(incorporated herein by reference to Exhibit 10.10(d) to the company's Quarterly Report on Form 10-Q filed
on May 8, 2025)
10.9(l)
Amended and Restated Indenture, dated August 10, 2025, related to Note Purchase Agreement dated
February 9, 2021, by Green Plains SPE LLC, as Issuer, Green Plains Inc., as Guarantor and Wilmington
Trust, National Association, as Trustee (incorporated herein by reference to Exhibit 10.11 to the company's
Quarterly Report on Form 10-Q filed on August 11, 2025)
**10.9(m)
Subscription Agreement, dated August 10, 2025, by and between Green Plains Inc., BlackRock Global
Allocation Fund, Inc., BlackRock Global Allocation Collective Fund, BlackRock Total Return Bond Fund,
and Strategic Income Opportunities Bond Fund (incorporated herein by reference to Exhibit 10.12 to the
company's Quarterly Report on Form 10-Q filed on August 11, 2025)
**10.9(n)
Pledge and Security Agreement dated August 10, 2025 by and among Green Plains Inc. and its subsidiaries,
individually and/or collectively as the Pledgor, in favor of Wilmington Trust, National Association, as
Trustee (incorporated herein by reference to Exhibit 10.13 to the company's Quarterly Report on Form 10-Q
filed on August 11, 2025)
**10.9(o)
Amended and Restated Pledge and Security Agreement dated August 10, 2025 by and among Green Plains
SPE LLC, as the Pledgor, in favor of Wilmington Trust, National Association, as Trustee (incorporated
herein by reference to Exhibit 10.14 to the company's Quarterly Report on Form 10-Q filed on August 11,
2025)
**10.9(p)
Pledge and Security Agreement dated August 10, 2025 by and among Green Plains York Capture Company
LLC, Green Plains Wood River Capture Company LLC and Green Plains Central City Capture Company
LLC individually and/or collectively as the Pledgor, in favor of Wilmington Trust, National Association, as
Trustee (incorporated herein by reference to Exhibit 10.15 to the company's Quarterly Report on Form 10-Q
filed on August 11, 2025)
**10.9(q)
Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated August 10, 2025, by and between
Green Plains Inc. and BlackRock Global Allocation Fund, Inc. (incorporated herein by reference to Exhibit
10.16(a) to the company's Quarterly Report on Form 10-Q filed on August 11, 2025)
**10.9(r)
Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated August 10, 2025, by and between
Green Plains Inc. and BlackRock Global Allocation Collective Fund (incorporated herein by reference to
Exhibit 10.16(b) to the company's Quarterly Report on Form 10-Q filed on August 11, 2025)
**10.9(s)
Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated August 10, 2025, by and between
Green Plains Inc. and Strategic Income Opportunities Bond Fund (incorporated herein by reference to
Exhibit 10.16(c) to the company's Quarterly Report on Form 10-Q filed on August 11, 2025)
**10.9(t)
Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated August 10, 2025, by and between
Green Plains Inc. and BlackRock Total Return Bond Fund (incorporated herein by reference to Exhibit
10.16(d) to the company's Quarterly Report on Form 10-Q filed on August 11, 2025)
**10.10(a)
Loan and Security Agreement, dated March 25, 2022, by and among Green Plains Inc., as Guarantor, Green
Plains Finance Company LLC, Green Plains Grain Company LLC and Green Plains Trade Group LLC as the
Borrowers, ING Capital LLC, as Agent and the other financial institutions party thereto. (incorporated herein
by reference to Exhibit 10.1 to the company's Current Report on Form 8-K filed on March 28, 2022).
**10.10(b) First Amendment to Loan and Security Agreement, dated April 14, 2025, related to Loan and Security
Agreement dated March 25, 2022, by and among Green Plains Inc., as Guarantor, Green Plains Finance
Company LLC, Green Plains Grain Company LLC and Green Plains Trade Group LLC as the Borrowers,
ING Capital LLC, as Agent and the other financial institutions party thereto (incorporated herein by
reference to Exhibit 10.7 to the company's Quarterly Report on Form 10-Q filed on May 8, 2025)
*10.11
Green Plains Inc. Executive Change in Control Severance Plan, dated August 2, 2023 (incorporated herein
by reference to Exhibit 10.2 to the company's Quarterly Report on Form 10-Q filed on August 4, 2023)
*10.12
Green Plains Inc. Director Compensation Program (incorporated herein by reference to Exhibit 10.31 to the
company's Annual Report on Form 10-K filed on February 9, 2024)
*10.13
Green Plains Partners LP 2015 Long-Term Incentive Plan (incorporated herein by reference to Exhibit 10.32
to the company's Annual Report on Form 10-K filed on February 9, 2024)
56
10.14
Cooperation Agreement, dated February 6, 2024, by and among Green Plains Inc. and Ancora Holdings
Group, LLC (incorporated herein by reference to Exhibit 10.1 to the company's Current Report on Form 8-K
filed on February 7, 2024)
*10.15(a)
Employment Agreement by and between Green Plains Inc. and Grant Kadavy, dated October 3, 2022
(incorporated herein by reference to Exhibit 10.1 to the company's Quarterly Report on Form 10-Q filed on
May 3, 2024)
*10.15(b)
Executive Change in Control Severance Plan Participation Letter by and between Green Plains Inc. and
Grant Kadavy, dated August 2, 2023 (incorporated herein by reference to Exhibit 10.2 to the company's
Quarterly Report on Form 10-Q filed on May 3, 2024)
*10.15(c)
Amendment No. 1 to Employment Agreement by and between Green Plains Inc. and Grant Kadavy dated
February 6, 2025 (incorporated herein by reference to Exhibit 10.29 to the company's Annual Report on
Form 10-K filed on February 7, 2025)
*10.15(d)
Confidential Severance Agreement and Release by and between Green Plains Inc. and Grant Kadavy dated
February 6, 2025 (incorporated herein by reference to Exhibit 10.30 to the company's Annual Report on
Form 10-K filed on February 7, 2025)
*10.16(a)
Employment Agreement by and between Green Plains Inc. and Phil Boggs, dated December 2, 2021
*10.16(b)
Amendment No. 1 to Employment Agreement by and between Green Plains Inc. and Phil Boggs effective
November 1, 2024 (incorporated herein by reference to Exhibit 10.1 to the company's Current Report on
Form 8-K/A filed on November 15, 2024)
*10.16(c)
Executive Change in Control Severance Plan Participation Letter - Amended and Restated by and between
Green Plains Inc. and Phil Boggs dated November 4, 2024 (incorporated herein by reference to Exhibit 10.2
to the company's Current Report on Form 8-K/A filed on November 15, 2024)
*10.16(d)
Confidential Severance Agreement and Release by and between Green Plains Inc. and Phil Boggs dated
January 5, 2026
10.17
Cooperation Agreement, dated April 11, 2025, by and between Green Plains Inc. and Ancora Holdings
Group, LLC (incorporated herein by reference to Exhibit 10.1 to the company's Current Report on Form 8-K
filed on April 15, 2025)
**10.18
Ethanol Marketing Agreement, dated April 16, 2025, by and between Green Plains Trade Group LLC and
Eco-Energy, LLC (incorporated herein by reference to Exhibit 10.1 to the company's Current Report on
Form 8-K filed on April 22, 2025)
10.19(a)
Secured Line of Credit Agreement, dated May 7, 2025 by Green Plains Inc., as Borrower, Green Plains
Central City LLC, as Guarantor and Ancora Alternatives LLC, as Lender (incorporated herein by reference to
Exhibit 10.11 to the company's Quarterly Report on Form 10-Q filed on May 8, 2025)
10.19(b)
Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated May 7, 2025, by and between
Green Plains Inc. and Ancora Catalyst Institutional, LP (incorporated herein by reference to Exhibit 10.12(a)
to the company's Quarterly Report on Form 10-Q filed on May 8, 2025)
10.19(c)
Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated May 7, 2025, by and between
Green Plains Inc. and Ancora Catalyst, LP (incorporated herein by reference to Exhibit 10.12(b) to the
company's Quarterly Report on Form 10-Q filed on May 8, 2025)
10.19(d)
Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated May 7, 2025, by and between
Green Plains Inc. and Ancora Merlin Institutional, LP (incorporated herein by reference to Exhibit 10.12(c)
to the company's Quarterly Report on Form 10-Q filed on May 8, 2025)
10.19(e)
Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated May 7, 2025, by and between
Green Plains Inc. and Ancora Merlin, LP (incorporated herein by reference to Exhibit 10.12(d) to the
company's Quarterly Report on Form 10-Q filed on May 8, 2025)
10.19(f)
Warrant Agreement to Purchase Common Stock of Green Plains Inc., dated May 7, 2025, by and between
Green Plains Inc. and Ancora Bellator Fund, LP (incorporated herein by reference to Exhibit 10.12(e) to the
company's Quarterly Report on Form 10-Q filed on May 8, 2025)
10.20
Sale, Assignment and Assumption Agreement, dated June 30, 2025, by and between Green Plains Turnkey I
LLC and Tharaldson Ethanol Plant I, LLC (incorporated herein by reference to Exhibit 10.10 to the
company's Quarterly Report on Form 10-Q filed on August 11, 2025)
57
*10.21(a)
Employment Agreement by and between Green Plains Inc. and Chris Osowski, effective August 19, 2025
(incorporated herein by reference to Exhibit 10.1 to the company's Current Report on Form 8-K filed on
August 19, 2025)
*10.21(b)
Executive Change in Control Severance Plan Participation Letter by and between Green Plains Inc. and
Chris Osowski, dated August 2, 2023 (incorporated herein by reference to Exhibit 10.3 to the company's
Quarterly Report on Form 10-Q filed on August 4, 2023)
10.22(a)
Tax Credit Purchase Agreement By and Between Green Plains Inc. and Freepoint Commodities C LLC
(incorporated herein by reference to Exhibit 10.1 to the company's Current Report on Form 8-K filed on
September 17, 2025)
10.22(b)
First Amendment to Tax Credit Purchase Agreement By and Between Green Plains Inc. and Freepoint
Commodities C LLC effective December 10, 2025
*10.23(a)
Offer Letter by and between Green Plains Inc. and Ann Reis, dated December 10, 2025 (incorporated herein
by reference to Exhibit 10.1 to the company's Current Report on Form 8-K filed on January 5, 2026)
*10.23(b)
Employment Agreement by and between Green Plains Inc. and Ann Reis, effective January 6, 2026
(incorporated herein by reference to Exhibit 10.2 to the company's Current Report on Form 8-K filed on
January 5, 2026)
*10.24(a)
Offer Letter by and between Green Plains Inc. and Ryan Loneman, dated January 8, 2026 (incorporated
herein by reference to Exhibit 10.1 to the company's Current Report on Form 8-K filed on January 12, 2026)
*10.24(b)
Employment Agreement by and between Green Plains Inc. and Ryan Loneman, effective January 26, 2026
(incorporated herein by reference to Exhibit 10.2 to the company's Current Report on Form 8-K filed on
January 12, 2026)
19.1
Green Plains Inc. Insider Trading Policy
21.1
Schedule of Subsidiaries
23.1
Consent of KPMG LLP
31.1
Certification of Chief Executive Officer pursuant to Rule 13a-14(a) and Section 302 of the Sarbanes-Oxley
Act of 2002
31.2
Certification of Chief Financial Officer pursuant to Rule 13a-14(a) and Section 302 of the Sarbanes-Oxley
Act of 2002
32.1
Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section
906 of the Sarbanes-Oxley Act of 2002
32.2
Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section
906 of the Sarbanes-Oxley Act of 2002
97
Green Plains Inc. Clawback Policy (incorporated herein by reference to Exhibit 97 to the company's Annual
Report on Form 10-K filed on February 9, 2024)
101
The following information from Green Plains Inc.’s Annual Report on Form 10-K for the annual period
ended December 31, 2025, formatted in Inline Extensible Business Reporting Language (iXBRL): (i) the
Consolidated Balance Sheets, (ii) the Consolidated Statements of Operations, (iii) the Consolidated
Statements of Comprehensive Loss (iv) the Consolidated Statements of Stockholders’ Equity (v) the
Consolidated Statements of Cash Flows and (vi) the Notes to Consolidated Financial Statements and
Financial Statement Schedule.
104
The cover page from Green Plains Inc. Annual Report on Form 10-K for the year ended December 31, 2025,
formatted in iXBRL
*
Represents management compensatory contracts
**
Pursuant to Item 601(a)(5) of Regulation S-K, certain schedules and similar attachments have been omitted.
The registrant hereby agrees to furnish a copy of any omitted schedule or similar attachment to the Securities
and Exchange Commission upon request.
Item 16. Form 10-K Summary.
None.
58
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly
caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
GREEN PLAINS INC
(Registrant)
Date: February 10, 2026
By: /s/ Chris G. Osowski
Chris G. Osowski
President and Chief Executive Officer
(Principal Executive Officer)
59
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following
persons on behalf of the registrant and in the capacities and on the dates indicated.
Signature
Title
Date
/s/ Chris G. Osowski
President and Chief Executive Officer
February 10, 2026
Chris G. Osowski
(Principal Executive Officer) and Director
/s/ Ann Reis
Chief Financial Officer (Principal Financial
February 10, 2026
Ann Reis
Officer and Principal Accounting Officer)
/s/ Jim Anderson
Chairman of the Board
February 10, 2026
Jim Anderson
/s/ Farha Aslam
Director
February 10, 2026
Farha Aslam
/s/ Steve Furcich
Director
February 10, 2026
Steve Furcich
/s/ Carl Grassi
Director
February 10, 2026
Carl Grassi
/s/ Brian D. Peterson
Director
February 10, 2026
Brian D. Peterson
/s/ Martin Salinas Jr.
Director
February 10, 2026
Martin Salinas Jr.
/s/ Patrick Sweeney
Director
February 10, 2026
Patrick Sweeney
/s/ Kimberly Wagner
Director
February 10, 2026
Kimberly Wagner
F-1
Report of Independent Registered Public Accounting Firm
To the Stockholders and Board of Directors
Green Plains Inc.:
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheets of Green Plains Inc. and subsidiaries (the Company) as of
December 31, 2025 and 2024, the related consolidated statements of operations, comprehensive loss, stockholders’ equity,
and cash flows for each of the years in the three-year period ended December 31, 2025, and the related notes (collectively, the
consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects,
the financial position of the Company as of December 31, 2025 and 2024, and the results of its operations and its cash flows
for each of the years in the three-year period ended December 31, 2025, in conformity with U.S. generally accepted
accounting principles.
We also have 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, 2025, 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 10, 2026 expressed an unqualified opinion on the effectiveness of the Company’s
internal control over financial reporting.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express
an opinion on these consolidated 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 consolidated 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 consolidated 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
consolidated 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 consolidated financial statements. We
believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial
statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or
disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective,
or complex judgments. The communication of a critical audit matter does not alter in any way our opinion on the
consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below,
providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Fair value of forward contracts
As discussed in Note 2 to the consolidated financial statements, the Company records forward contracts at fair value
unless the contract qualifies for and the Company elects normal purchase or sale exceptions. The Company estimates a
fair value based on exchange-quoted prices, adjusted as appropriate for regional location basis values, which represent
differences in local markets including transportation as well as quality or grade differences. Basis values are generally
determined using inputs from broker quotations or other market transactions. As of December 31, 2025, the recorded
balances of the Company’s derivative assets and liabilities associated with forward contracts were $6,927 thousand and
$7,901 thousand, respectively, and are classified as Level 2 assets and liabilities within Notes 5 and 10.
We identified the assessment of the valuation of forward contracts as a critical audit matter. Specifically, evaluating the
valuation of forward contracts, which included assumptions related to exchange-quoted prices, and adjustments for
regional location basis values, involved complex auditor judgment due to the subjectivity involved in determining the
fair value.
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and
tested the operating effectiveness of certain internal controls related to the valuation of forward contracts. To assess the
valuation of forward contracts, for a sample of contracts, we tested the Company’s exchange-quoted prices by comparing
F-2
the amounts used to observable market transactions and evaluated the Company’s adjustments for regional location basis
values by comparing inputs used by the Company to third-party information, including broker quotations or other market
transactions.
/s/ KPMG LLP
We have served as the Company’s auditor since 2009.
Omaha, Nebraska
February 10, 2026
F-3
GREEN PLAINS INC.
CONSOLIDATED BALANCE SHEETS
(in thousands, except share amounts)
December 31,
2025
2024
ASSETS
Current assets
Cash and cash equivalents
$
182,319 $
173,041
Restricted cash
47,813
36,354
Accounts receivable, net of allowances of $801 and $80, respectively
74,374
94,901
Inventories
148,095
227,444
Prepaid expenses and other
18,117
27,138
Derivative financial instruments
11,494
10,154
Total current assets
482,212
569,032
Property and equipment, net
957,256
1,042,460
Operating lease right-of-use assets
63,849
72,161
Deferred income taxes, net
33,837
—
Other assets
41,242
98,521
Total assets
$
1,578,396 $
1,782,174
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Accounts payable
$
134,912 $
154,817
Accrued and other liabilities
66,828
53,712
Derivative financial instruments
7,901
9,500
Operating lease current liabilities
21,557
24,711
Short-term notes payable and other borrowings
33,584
140,829
Current maturities of long-term debt
3,924
2,118
Total current liabilities
268,706
385,687
Long-term debt
361,992
432,460
Operating lease long-term liabilities
43,648
49,190
Carbon equipment liabilities
104,217
17,918
Other liabilities
27,862
22,382
Total liabilities
806,425
907,637
Commitments and contingencies (Note 16)
Stockholders' equity
Common stock, $0.001 par value; 150,000,000 shares authorized; 75,495,731 and 67,512,282
shares issued, and 69,828,077 and 64,707,223 shares outstanding, respectively
76
68
Additional paid-in capital
1,267,839
1,213,646
Retained deficit
(439,576)
(318,298)
Accumulated other comprehensive income (loss)
(618)
973
Treasury stock, 5,667,654 and 2,805,059 shares, respectively
(61,474)
(31,174)
Total Green Plains stockholders' equity
766,247
865,215
Noncontrolling interests
5,724
9,322
Total stockholders' equity
771,971
874,537
Total liabilities and stockholders' equity
$
1,578,396 $
1,782,174
See accompanying notes to the consolidated financial statements.
F-4
GREEN PLAINS INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
(in thousands, except per share amounts)
Year Ended December 31,
2025
2024
2023
Revenues
$
2,091,680 $
2,458,796 $
3,295,743
Costs and expenses
Cost of goods sold (excluding depreciation and amortization expenses reflected
below)
1,954,754
2,328,346
3,130,992
Selling, general and administrative expenses
122,713
118,045
133,350
Gain on sale of assets, net
(31,535)
(30,723)
(5,265)
Depreciation and amortization expenses
98,434
90,587
98,244
Impairment of assets held for sale
14,562
—
—
Total costs and expenses
2,158,928
2,506,255
3,357,321
Operating loss
(67,248)
(47,459)
(61,578)
Other income (expense)
Interest income
4,180
7,560
11,707
Interest expense
(76,668)
(33,095)
(37,703)
Other, net
(4,081)
1,696
5,225
Total other income (expense)
(76,569)
(23,839)
(20,771)
Loss before income taxes and income (loss) from equity method investees
(143,817)
(71,298)
(82,349)
Income tax benefit (expense)
51,746
(6,212)
5,617
Income (loss) from equity method investees, net of income taxes
(28,929)
(3,679)
433
Net loss
(121,000)
(81,189)
(76,299)
Net income attributable to noncontrolling interests
278
1,308
17,085
Net loss attributable to Green Plains
$
(121,278) $
(82,497) $
(93,384)
Earnings per share
Net loss attributable to Green Plains - basic and diluted
$
(1.80) $
(1.29) $
(1.59)
Weighted average shares outstanding
Basic and diluted
67,496
63,796
58,814
See accompanying notes to the consolidated financial statements.
F-5
GREEN PLAINS INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS
(in thousands)
Year Ended December 31,
2025
2024
2023
Net loss
$
(121,000) $
(81,189) $
(76,299)
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on derivatives arising during the period, net of
tax benefit (expense) of $3,065, $1,919 and $(2,021), respectively
(9,099)
(6,082)
6,348
Reclassification of realized losses on derivatives, net of tax benefit of
($2,529), ($3,223) and ($5,438), respectively
7,508
10,215
17,083
Total other comprehensive income (loss), net of tax
(1,591)
4,133
23,431
Comprehensive loss
(122,591)
(77,056)
(52,868)
Comprehensive income attributable to noncontrolling interests
278
1,308
17,085
Comprehensive loss attributable to Green Plains
$
(122,869) $
(78,364) $
(69,953)
See accompanying notes to the consolidated financial statements.
F-6
GREEN PLAINS INC.
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
(in thousands)
Common
Stock
Additional
Paid-in
Capital
Retained
(Deficit)
Accumulated
Other
Comprehensive
Income (Loss)
Treasury Stock
Total
Green Plains
Stockholders'
Equity
Non-
Controlling
Interests
Total
Stockholders'
Equity
Shares
Amount
Shares
Amount
Balance, January 1, 2023
62,101 $
62 $ 1,110,151 $ (142,417) $
(26,591)
2,805 $ (31,174) $
910,031 $
151,035 $
1,061,066
Net income (loss)
—
—
—
(93,384)
—
—
—
(93,384)
17,085
(76,299)
Cash dividends and
distributions declared
—
—
—
—
—
—
—
—
(22,728)
(22,728)
Other comprehensive income
before reclassification
—
—
—
—
6,348
—
—
6,348
—
6,348
Amounts reclassified from
accumulated other
comprehensive loss
—
—
—
—
17,083
—
—
17,083
—
17,083
Other comprehensive income,
net of tax
—
—
—
—
23,431
—
—
23,431
—
23,431
Investment in subsidiaries
—
—
—
—
—
—
—
—
572
572
Stock-based compensation
226
—
3,655
—
—
—
—
3,655
359
4,014
Balance, December 31, 2023
62,327
62 1,113,806
(235,801)
(3,160)
2,805 (31,174)
843,733
146,323
990,056
Net income (loss)
—
—
—
(82,497)
—
—
—
(82,497)
1,308
(81,189)
Distributions declared
—
—
—
—
—
—
—
—
(5,165)
(5,165)
Other comprehensive loss
before reclassification
—
—
—
—
(6,082)
—
—
(6,082)
—
(6,082)
Amounts reclassified from
accumulated other
comprehensive loss
—
—
—
—
10,215
—
—
10,215
—
10,215
Other comprehensive income,
net of tax
—
—
—
—
4,133
—
—
4,133
—
4,133
Partnership Merger
4,746
5
97,035
—
—
—
—
97,040
(133,765)
(36,725)
Investment in subsidiaries
—
—
(769)
—
—
—
—
(769)
621
(148)
Stock-based compensation
439
1
3,574
—
—
—
—
3,575
—
3,575
Balance, December 31, 2024
67,512
68 1,213,646
(318,298)
973
2,805 (31,174)
865,215
9,322
874,537
Net income (loss)
—
—
—
(121,278)
—
—
—
(121,278)
278
(121,000)
Distributions declared
—
—
—
—
—
—
—
—
(1,256)
(1,256)
Other comprehensive loss
before reclassification
—
—
—
—
(9,099)
—
—
(9,099)
—
(9,099)
Amounts reclassified from
accumulated other
comprehensive loss
—
—
—
—
7,508
—
—
7,508
—
7,508
Other comprehensive loss, net
of tax
—
—
—
—
(1,591)
—
—
(1,591)
—
(1,591)
Investment in subsidiaries
—
—
—
—
—
—
—
—
1,914
1,914
Proventus disposition
—
—
—
—
—
—
—
—
(4,534)
(4,534)
Issuance of warrants
—
—
24,131
—
—
—
—
24,131
—
24,131
Modification of warrants
—
—
7,520
—
—
—
—
7,520
—
7,520
Exercise of warrants
7,050
7
7,575
—
—
—
—
7,582
—
7,582
Share repurchase
—
—
—
—
—
2,863 (30,300)
(30,300)
—
(30,300)
Stock-based compensation
940
1
14,967
—
—
—
—
14,968
—
14,968
Balance, December 31, 2025
75,502 $
76 $ 1,267,839 $ (439,576) $
(618)
5,668 $ (61,474) $
766,247 $
5,724 $
771,971
See accompanying notes to the consolidated financial statements.
F-7
GREEN PLAINS INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)
Year Ended December 31,
2025
2024
2023
Cash flows from operating activities
Net loss
$
(121,000) $
(81,189) $
(76,299)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities
Depreciation and amortization
98,434
90,587
98,244
Amortization of debt issuance costs and non-cash interest expense
9,967
2,277
2,693
Gain on the sale of assets, net
(31,535)
(30,723)
(5,265)
Impairment of assets held for sale
14,562
—
—
Inventory lower of cost or net realizable value adjustment
1,463
2,143
2,627
Loss on extinguishment of debt
36,906
1,763
—
Deferred income taxes
(52,985)
3,944
(6,855)
Stock-based compensation
17,122
8,274
13,032
Loss (income) from equity method investees, net of income taxes
28,929
3,679
(433)
Distribution from equity method investees
—
575
—
Other
9,943
165
2,203
Changes in operating assets and liabilities before effects of asset dispositions
Accounts receivable
19,271
(455)
14,164
Inventories
66,657
(12,745)
53,472
Derivative financial instruments
8,740
13,980
(2,919)
Prepaid expenses and other assets
13,694
(5,165)
(3,704)
Accounts payable and accrued liabilities
(16,188)
(27,907)
(34,573)
Current income taxes
4,724
(285)
497
Other
2,160
1,117
(538)
Net cash provided by (used in) operating activities
110,864
(29,965)
56,346
Cash flows from investing activities
Purchases of property and equipment, net
(37,199)
(95,084)
(108,093)
Proceeds from the sale of assets, net
179,909
48,704
25,403
Proceeds for the sale of equity method investment
24,332
—
—
Investment in equity method investees, net
(4,909)
(15,672)
(24,206)
Net cash provided by (used in) investing activities
162,133
(62,052)
(106,896)
Cash flows from financing activities
Proceeds from the issuance of long-term debt
30,000
—
—
Payments of principal on long-term debt
(132,598)
(61,697)
(4,838)
Proceeds from short-term borrowings
397,942
758,095
1,190,999
Payments on short-term borrowings
(505,644)
(724,133)
(1,223,785)
Net proceeds from product financing arrangement
3,395
—
—
Payments for repurchase of common stock
(30,000)
—
—
Payments on extinguishment of non-controlling interest
—
(29,196)
—
Payments of dividends and distributions
(721)
(5,165)
(22,728)
Payments of transaction costs
—
(5,951)
—
Payments of loan fees
(9,220)
(1,544)
(16)
Payments related to tax withholdings for stock-based compensation
(2,155)
(4,699)
(9,018)
Other financing activities
(3,259)
(3,060)
(1,578)
Net cash used in financing activities
(252,260)
(77,350)
(70,964)
Net change in cash and cash equivalents, and restricted cash
20,737
(169,367)
(121,514)
Cash and cash equivalents, and restricted cash, beginning of period
209,395
378,762
500,276
Cash and cash equivalents, and restricted cash, end of period
$
230,132 $
209,395 $
378,762
Continued on the following page
F-8
GREEN PLAINS INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)
Continued from the previous page
Year Ended December 31,
2025
2024
2023
Reconciliation of total cash and cash equivalents, and restricted cash
Cash and cash equivalents
$
182,319 $
173,041 $
349,574
Restricted cash
47,813
36,354
29,188
Total cash and cash equivalents, and restricted cash
$
230,132 $
209,395 $
378,762
Non-cash financing activity
Issuance of common stock as a result of the Merger
$
— $
5 $
—
Extinguishment of non-controlling interest within additional paid-in
capital
$
— $
133,765 $
—
Supplemental investing activities
Assets disposed of in sale
$
150,402 $
21,027 $
22,351
Less: liabilities relinquished
(12,376)
(3,295)
(3,779)
Net assets disposed
$
138,026 $
17,732 $
18,572
Supplemental disclosures of cash flow
Cash paid for income taxes, net
$
1,768 $
486 $
1,242
Cash paid for interest
$
35,152 $
31,314 $
35,161
Capital expenditures in accounts payable
$
2,548 $
5,502 $
7,001
Capital expenditures in long-term debt
$
34,523 $
— $
—
Capital expenditures in other liabilities
$
104,217 $
17,918 $
—
Non-cash asset retirement obligation additions
$
16,035 $
1,492 $
3,013
See accompanying notes to the consolidated financial statements.
F-9
GREEN PLAINS INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. BASIS OF PRESENTATION AND DESCRIPTION OF BUSINESS
References to the Company
References to “Green Plains” or the “company” in the consolidated financial statements and in these notes to the
consolidated financial statements refer to Green Plains Inc., an Iowa corporation, and its subsidiaries.
Consolidated Financial Statements
The consolidated financial statements include the company’s accounts, and all significant intercompany balances and
transactions are eliminated. Unconsolidated entities are included in the financial statements on an equity basis. The company
also owns a majority interest in FQT, with their results being consolidated in our consolidated financial statements.
On January 9, 2024, the transactions contemplated by the Merger Agreement were completed and the company acquired
all of the publicly held common units of the partnership not already owned by the company and its affiliates. Refer to Note 4
– Merger and Dispositions included herein for more information.
Reclassifications
Certain prior year amounts have been reclassified to conform to the current year presentation. These reclassifications did
not affect total assets, liabilities, or equity on the consolidated balance sheets, but separately disclose comparable balances of
liabilities previously disclosed within other liabilities.
Use of Estimates in the Preparation of Consolidated Financial Statements
The preparation of consolidated financial statements in conformity with GAAP requires management to make certain
estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and
liabilities at the date of the consolidated financial statements, and the reported amounts of revenues and expenses during the
reporting period. The company bases its estimates on historical experience and assumptions it believes are proper and
reasonable under the circumstances and regularly evaluates the appropriateness of its estimates and assumptions. Actual
results could differ from those estimates. Certain accounting policies, including but not limited to 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 financial statements.
Description of Business
The company operates within two operating segments: (1) ethanol production, which includes the production, storage
and transportation of ethanol, distillers grains, Ultra-High Protein and renewable corn oil 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.
•
Ethanol Production. Our ethanol production segment includes the production, storage and transportation of ethanol,
distillers grains, Ultra-High Protein and renewable corn oil at nine biorefineries in Illinois, Indiana, Iowa, Minnesota
and Nebraska. At capacity, our 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.
We are one of the largest ethanol producers in North America.
•
Agribusiness and Energy Services. Our agribusiness and energy services segment includes grain procurement,
storage and commodity marketing. We market our ethanol through a 3rd 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.
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2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Cash and Cash Equivalents
Cash and cash equivalents include bank deposits as well as short-term, highly liquid investments with original maturities
of three months or less.
Restricted Cash
The company has restricted cash, which can only be used for funding letters of credit and for payment towards a credit
agreement. Restricted cash also includes cash margins and securities pledged to commodity exchange clearinghouses. To the
degree these segregated balances are cash and cash equivalents, they are considered restricted cash on the consolidated
balance sheets.
Revenue Recognition
The company recognizes revenue when obligations under the terms of a contract with a customer are satisfied. Generally,
this occurs with the transfer of control of products or services. Revenue is measured as the amount of consideration expected
to be received in exchange for transferring goods or providing services. Sales, value add, and other taxes the company
collects concurrent with revenue-producing activities are excluded from revenue.
Sales of ethanol, distillers grains, Ultra-High Protein, renewable corn oil, natural gas and other commodities by the
company’s marketing business are recognized when obligations under the terms of a contract with a customer are satisfied.
Generally, this occurs with the transfer of control of products or services. Revenues related to marketing for third parties are
presented on a gross basis as the company controls the product prior to the sale to the end customer, takes title of the product
and has inventory risk. Unearned revenue is recorded for goods in transit when the company has received payment but
control has not yet been transferred to the customer. Revenues for receiving, storing, transferring and transporting ethanol and
other fuels are recognized when the product is delivered to the customer.
The company routinely enters into physical-delivery energy commodity purchase and sale agreements. At times, the
company settles these transactions by transferring its obligations to other counterparties rather than delivering the physical
commodity. Revenues include net gains or losses from derivatives related to products sold while cost of goods sold includes
net gains or losses from derivatives related to commodities purchased. Revenues also include realized gains and losses on
related derivative financial instruments and reclassifications of realized gains and losses on cash flow hedges from
accumulated other comprehensive income or loss.
Sales of products are recognized when control of the product is transferred to the customer, which depends on the agreed
upon shipment or delivery terms.
Shipping and Handling Costs
The company accounts for shipping and handling activities related to contracts with customers as costs to fulfill its
promise to transfer the associated products. Accordingly, the company records customer payments associated with shipping
and handling costs as a component of revenue, and classifies such costs as a component of cost of goods sold.
Cost of Goods Sold
Cost of goods sold includes materials, direct labor, shipping, plant overhead and transportation costs. Materials include
the cost of corn feedstock, denaturant, and process chemicals. Corn feedstock costs include gains and losses on related
derivative financial instruments not designated as cash flow hedges, inbound freight charges, inspection costs and transfer
costs, as well as reclassifications of gains and losses on cash flow hedges from accumulated other comprehensive income or
loss. Direct labor includes all compensation and related benefits of non-management personnel involved in production.
Shipping costs incurred by the company, including railcar costs, are also reflected in cost of goods sold. Plant overhead
consists primarily of plant utilities, repairs and maintenance and outbound freight charges. Transportation costs include
railcar leases, freight and shipping of the company's products, as well as storage costs incurred at destination terminals.
The company uses exchange-traded futures and options contracts and forward purchase and sale contracts to attempt to
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minimize the effect of price changes on ethanol, renewable corn oil, grain and natural gas. Exchange-traded futures and
options contracts are valued at quoted market prices and settled predominantly in cash. The company is exposed to loss when
counterparties default on forward purchase and sale contracts. Grain inventories held for sale and forward purchase and sale
contracts are valued at market prices when available or other market quotes adjusted for basis differences, primarily in
transportation, between the exchange-traded market and local market where the terms of the contract are based. Changes in
forward purchase contracts and exchange-traded futures and options contracts are recognized as a component of cost of goods
sold.
Derivative Financial Instruments
The company uses various derivative financial instruments, including exchange-traded futures and exchange-traded and
over-the-counter options contracts, to attempt to minimize risk and the effect of commodity price changes including but not
limited to, corn, ethanol, natural gas and other agricultural and energy products. The company monitors and manages this
exposure as part of its overall risk management policy to reduce the adverse effect market volatility may have on its operating
results. The company may hedge these commodities as one way to mitigate risk; however, there may be situations when these
hedging activities themselves result in losses.
By using derivatives to hedge exposures to changes in commodity prices, the company is exposed to credit and market
risk. The company’s exposure to credit risk includes the counterparty’s failure to fulfill its performance obligations under the
terms of the derivative contract. The company minimizes its credit risk by entering into transactions with high quality
counterparties, limiting the amount of financial exposure it has with each counterparty and monitoring their financial
condition. Market risk is the risk that the value of the financial instrument might be adversely affected by a change in
commodity prices or interest rates. The company manages market risk by incorporating parameters to monitor exposure
within its risk management strategy, which limits the types of derivative instruments and strategies the company can use and
the degree of market risk it can take using derivative instruments.
Forward contracts are recorded at fair value unless the contracts qualify for, and the company elects, normal purchase or
sale exceptions. Changes in fair value are recorded in operating income unless the contracts qualify for, and the company
elects, cash flow hedge accounting treatment.
Certain qualifying derivatives related to ethanol production and agribusiness and energy services are designated as cash
flow hedges. The company evaluates the derivative instrument to ascertain its effectiveness prior to entering into cash flow
hedges. Unrealized gains and losses are reflected in accumulated other comprehensive income or loss until the gain or loss
from the underlying hedged transaction is realized and the physical transaction is completed. When it becomes probable a
forecasted transaction will not occur, the cash flow hedge treatment is discontinued, which affects earnings. These derivative
financial instruments are recognized in current assets or current liabilities at fair value.
At times, the company hedges its exposure to changes in inventory values and designates qualifying derivatives as fair
value hedges. The carrying amount of the hedged inventory is adjusted in the current period for changes in fair value.
Estimated fair values carried at market are based on exchange-quoted prices, adjusted as appropriate for regional location
basis values which represent differences in local markets including transportation as well as quality or grade differences.
Basis values are generally determined using inputs from broker quotations or other market transactions. However, a portion
of the value may be derived using unobservable inputs. Ineffectiveness of the hedges is recognized in the current period to the
extent the change in fair value of the inventory is not offset by the change in fair value of the derivative.
Concentrations of Credit Risk
The company is exposed to credit risk resulting from the possibility that another party may fail to perform according to
the terms of the company’s contract. The company sells ethanol, distillers grains, Ultra-High Protein and renewable corn oil,
which can result in concentrations of credit risk from a variety of customers, including major integrated oil companies, large
independent refiners, petroleum wholesalers and other marketers. The company also sells grain to large commercial buyers.
Although payments are typically received within fifteen days of the sale, the company continually monitors its exposure. The
company is also exposed to credit risk on prepayments of undelivered inventories with a few major suppliers of petroleum
products and agricultural inputs.
The company has master netting arrangements with various counterparties for ethanol sales and related marketing fees
and the purchase and sale of natural gas. On the consolidated balance sheets, the associated net amount for each counterparty
is reflected as either an accounts receivable or accounts payable. If the amount for each counterparty were reflected on a
F-12
gross basis, the company's accounts receivable and accounts payable would increase by $5.9 million and $0.5 million at
December 31, 2025 and 2024, respectively.
Inventories
Corn held for ethanol production, ethanol, distillers grain, Ultra-High Protein, and renewable corn oil inventories are
recorded at the lower of average cost or net realizable value, except fair-value hedged inventories.
Property and Equipment
Property and equipment are stated at cost less accumulated depreciation. Depreciation is generally calculated using the
straight-line method over the following estimated useful life of the assets:
Years
Buildings and improvements
10-40
Plant equipment
10-40
Other machinery and equipment
5-7
Land improvements
15-40
Railroad track and equipment
20-30
Computer hardware and software
3-5
Office furniture and equipment
5-7
Property and equipment is capitalized at cost. Land improvements, interest incurred during construction and other
property improvements are capitalized and depreciated. Betterment of property assets are those that extend the useful life,
increase the capacity or improve the operating efficiency or improve the safety of our operations. Costs of repairs and normal
maintenance are charged to expense when incurred. The company periodically evaluates whether events and circumstances
have occurred that warrant a revision of the estimated useful life of its fixed assets.
Intangible Assets
Our intangible assets consist primarily of customer relationships, intellectual property, and licenses. These intangible
assets were capitalized at fair market value and are being amortized over their estimated useful lives.
Assets Held for Sale
In accordance with ASC 360, Property, Plant, Equipment, the company determined the carrying values of certain assets
classified as held for sale were not recoverable and exceeded their fair values. The company then measured the impairment
losses by comparing the book values with current third-party quoted market prices, resulting in a total impairment of
$14.6 million, which is recorded within impairment of assets held for sale in the ethanol production segment on the
consolidated statements of operations for the year ended December 31, 2025. After the impairment, we have $2.0 million of
assets held for sale as of December 31, 2025, which were recorded in the ethanol production segment within property and
equipment, net of accumulated depreciation and amortization on the consolidated balance sheets.
Impairment of Long-Lived Assets
The company reviews its long-lived assets, currently consisting of property and equipment, operating lease right-of-use
assets, intangible assets and equity method investments, for impairment whenever events or changes in circumstances
indicate the carrying amount of the asset may not be recoverable. Recoverability of assets to be held and used is measured by
comparison of the carrying amount of an asset to estimated undiscounted future cash flows expected to be generated by the
asset. If the carrying amount of an asset exceeds its estimated future cash flows, an impairment charge is recognized in the
amount by which the carrying amount of the asset exceeds the fair value of the asset. Significant management judgment is
required to determine the fair value of our long-lived assets and measure impairment, which includes projected cash flows.
Fair value is determined by using various valuation techniques, including discounted cash flow models, sales of comparable
properties and third-party independent appraisals. Changes in estimated fair value could result in an impairment of the asset.
F-13
Goodwill
Goodwill is an asset representing the future economic benefits arising from other assets acquired in a business
combination that are not individually identified and separately recognized. The determination of goodwill takes into
consideration the fair value of net tangible and intangible assets. The company’s goodwill is related to an acquisition within
our ethanol production segment.
The company is required to perform impairment tests related to goodwill annually, which it performs as of October 1, or
if an indicator of impairment occurs. Circumstances that may indicate impairment include a decline in the company’s future
projected cash flows, a decision to suspend plant operations for an extended period of time, sustained decline in the
company’s market capitalization or market prices for similar assets or businesses, or a significant adverse change in legal or
regulatory matters or business climate. Significant management judgment is required to determine the fair value of goodwill
and measure impairment, which include, but are not limited to, market capitalization, prospective financial information,
growth rates, discount rates, inflationary factors, and cost of capital. Fair value is determined by using various valuation
techniques, including discounted cash flow models, sales of comparable properties and third-party independent appraisals.
Changes in estimated fair value could result in a write-down of the asset.
Leases
The company leases certain facilities, parcels of land, and equipment. These leases are accounted for as operating leases,
with lease expense recognized on a straight-line basis over the lease term. The term of the lease may include options to
extend or terminate the lease when it is reasonably certain that such options will be exercised. For leases with initial terms
greater than 12 months, the company records operating lease right-of-use assets and corresponding operating lease liabilities.
Leases with an initial term of 12 months or less are not recorded on the consolidated balance sheet. The company did not
incur any material short-term lease expense for the years ended December 31, 2025, 2024 or 2023.
Operating lease right-of-use assets represent the right to control an underlying asset for the lease term and operating lease
liabilities represent the obligation to make lease payments arising from the lease. These assets and liabilities are recognized at
the commencement date based on the present value of lease payments over the lease term. As the company’s leases do not
provide an implicit rate, the incremental borrowing rate is used based on information available at commencement date to
determine the present value of future payments.
The company elected to utilize a portfolio approach for lease classification, which allows for an entity to group together
leases with similar characteristics provided that its application does not create a material difference when compared to
accounting for the leases at a contract level. For railcar leases, the company elected to combine the railcars within each rider
and account for each rider as an individual lease.
From a lessee perspective, the company combines both the lease and non-lease components and accounts for them as one
lease. Certain of the company’s railcar agreements provide for maintenance costs to be the responsibility of the company as
incurred or charged by the lessor. This maintenance cost is a non-lease component that the company combines with the
monthly rental payment and accounts for the total cost as operating lease expense. In addition, the company has a land lease
that contains a non-lease component for the handling and unloading services the landlord provides. The company combines
the cost of services with the land lease cost and accounts for the total as operating lease expense.
Investments in Equity Method Investees
The company accounts for investments in which the company exercises significant influence using the equity method so
long as the company (i) does not control the investee and (ii) is not the primary beneficiary of the entity. The company
recognizes these investments as a separate line item in the consolidated balance sheets and its proportionate share of earnings
on a separate line item in the consolidated statements of operations.
The company recognizes losses in the value of equity method investments when there is evidence of an other-than-
temporary decrease in value. Evidence of a loss might include, but would not necessarily be limited to, the inability to
recover the carrying amount of the investment or the inability of the equity method investee to sustain an earnings capacity
that justifies the carrying amount of the investment. The current fair value of an investment that is less than its carrying
amount may indicate a loss in value of the investment. The company evaluates equity method investments for impairment if
there is evidence an investment may be impaired. Distributions paid to the company from unconsolidated affiliates are
classified as operating activities in the consolidated statements of cash flows until the cumulative distributions exceed the
F-14
company’s proportionate share of income from the unconsolidated affiliate since the date of initial investment. The amount of
cumulative distributions paid to the company that exceeds the cumulative proportionate share of income in each period
represents a return of investment, which is classified as an investing activity in the consolidated statements of cash flows.
On June 30, 2025, the company disposed of its 50% investment in GP Turnkey Tharaldson, which was accounted for on
an equity method basis. Refer to Note 4 - Merger and Dispositions for further analysis. As of December 31, 2024, our equity
method investments consisted primarily of our 50% investment in GP Turnkey Tharaldson, which totaled $51.6 million and is
reflected in other assets on the consolidated balance sheet.
Product Financing Arrangement
During the second quarter of 2025, the company entered into a product financing arrangement with a financial institution
in which it received up front payment for corn oil that the company has an obligation to repurchase in weekly increments
through January of 2026. In accordance with ASC 606, Revenue from Contracts with Customers ("ASC 606"), this agreement
was accounted for as a financing transaction and revenue is precluded. As of December 31, 2025, a liability of $3.4 million
was recorded within accrued and other liabilities on the consolidated balance sheets.
Carbon Equipment Liabilities
The company engaged Tallgrass High Plains Carbon Storage, LLC and its affiliates to construct carbon sequestration
equipment at its three Nebraska plants in order to maximize tax credit potential related to the production of low carbon fuels.
The equipment build is in the final stages at two of our Nebraska plants as of December 31, 2025, and the company has
executed a financing agreement in which the cost of the project will be paid monthly over 12 years commencing once the
projects have reached substantial completion. Of the three projects, one has reached substantial completion and has been
recorded within debt as of December 31, 2025. The total spend related to the other two Nebraska CCS construction projects
has been recorded within carbon equipment liabilities on the consolidated balance sheets. While fully operational as of
December 31, 2025, these two projects did not reach substantial completion until January of 2026. The amounts presented as
carbon equipment liabilities will be reclassified and presented as debt on the consolidated balance sheets in January of 2026.
Financing Costs
Fees and costs related to securing debt are recorded as financing costs. Debt issuance costs are stated at cost and are
amortized using the effective interest method for term loans and the straight-line basis over the life of the agreements for
revolving credit arrangements and convertible notes.
Selling, General and Administrative Expenses
Selling, general and administrative expenses consist of various expenses including employee salaries, incentives and
benefits; office expenses; director compensation; professional fees for accounting, legal, consulting, and investor relations
activities.
Stock-Based Compensation
The company recognizes compensation cost using a fair value based method whereby compensation cost is measured at
the grant date based on the market price of the award on the date of the award agreement, or an estimated fair value for
market-based awards, and is recognized over the service period on a straight-line basis, which is usually the vesting period.
Income Taxes
The provision for income taxes is computed using the asset and liability method, under which deferred tax assets and
liabilities are recognized for the expected future tax consequences attributable to temporary differences between the financial
reporting carrying amount of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities
are measured using enacted tax rates expected to apply to taxable income in years in which those temporary differences are
expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in
operating results in the period of enactment. Deferred tax assets are reduced by a valuation allowance when it is more likely
than not that some portion or all of the deferred tax assets will not be realized.
The company recognizes uncertainties in income taxes within the financial statements under a process by which the
F-15
likelihood of a tax position is gauged based upon the technical merits of the position, and then a subsequent measurement
relates the maximum benefit and the degree of likelihood to determine the amount of benefit recognized in the financial
statements.
The company has determined that it qualifies for clean fuel production tax credits allowable under the IRA and OBBB.
The credits are recognized as a tax benefit in the period in which production occurs, and the product is sold in a qualifying
manner. The tax benefit recognized is determined based on the company's CI score to date and the expected sales price of the
credits. The credits are recorded within income tax benefit (expense) on the consolidated statements of operations.
Recent Accounting Pronouncements
In December 2025, the FASB issued ASU 2025-10, Accounting for Government Grants Received by Business Entities.
This ASU establishes a unified accounting model for business entities when recognizing, measuring, and presenting
government grants. The ASU categorizes grants as either related to an asset or related to income. A grant related to income is
recognized in earnings in a systematic and rational manner over the periods in which the entity recognizes the related
expenses. Presentation of the grant on the income statement can be either as a component of other income or as a deduction
from the related expenses. The standard is effective for annual periods beginning after December 15, 2028. However, the
ASU permits early adoption. The company is considering early adopting the provisions of ASU 2025-10 effective in the first
quarter of 2026 and is still assessing the impact on its financial statements, including the presentation of its Section 45Z
production tax credits.
In November 2024, the FASB issued ASU 2024-03, Income Statement - Reporting Comprehensive Income - Expense
Disaggregation Disclosures (Subtopic 220-40), which provides clarity in assessing an entity's performance and prospects for
future cash flows by disclosure of more detailed information about the types of expenses in commonly presented expense
captions. ASU 2024-03 is effective for the company's fiscal year ended December 31, 2027. Early adoption is permitted. The
company is currently evaluating the impact of this ASU.
In December 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740) - Improvements to Income Tax Disclosures
to enhance the transparency and decision usefulness of income tax disclosures. ASU 2023-09 is effective for the company's
fiscal year ended December 31, 2025. The ASU indicates that all entities will apply its guidance prospectively with an option
for retroactive application to each period in the financial statements. The company has adopted this ASU on a prospective
basis.
3. REVENUE
Revenue Recognition
Revenue is recognized when obligations under the terms of a contract with a customer are satisfied. Generally this occurs
with the transfer of control of products or services. Revenue is measured as the amount of consideration expected to be
received in exchange for transferring goods or providing services. Sales, value add, and other taxes the company collects
concurrent with revenue-producing activities are excluded from revenue.
F-16
Revenue by Source
The following tables disaggregate revenue by major source (in thousands):
Twelve Months Ended December 31, 2025
Ethanol
Production
Agribusiness &
Energy Services
Eliminations
Total
Revenues
Revenues from contracts with customers under ASC 606
Ethanol
$
— $
— $
— $
—
Distillers grains
83,613
11,785
—
95,398
Renewable corn oil
—
—
—
—
Other
89,895
3,686
—
93,581
Intersegment revenues
860
259
(1,119)
—
Total revenues from contracts with customers
174,368
15,730
(1,119)
188,979
Revenues from contracts accounted for as derivatives under ASC 815
(1)
Ethanol
1,372,928
116,300
—
1,489,228
Distillers grains
201,674
16,830
—
218,504
Renewable corn oil
152,888
—
—
152,888
Other
—
42,081
—
42,081
Intersegment revenues
—
22,402
(22,402)
—
Total revenues from contracts accounted for as derivatives
1,727,490
197,613
(22,402)
1,902,701
Total Revenues
$
1,901,858 $
213,343 $
(23,521) $
2,091,680
Twelve Months Ended December 31, 2024
Ethanol
Production
Agribusiness &
Energy Services
Eliminations
Total
Revenues
Revenues from contracts with customers under ASC 606
Ethanol
$
— $
— $
— $
—
Distillers grains
88,660
10,015
—
98,675
Renewable corn oil
—
—
—
—
Other
55,613
8,685
—
64,298
Intersegment revenues
3,707
287
(3,994)
—
Total revenues from contracts with customers
147,980
18,987
(3,994)
162,973
Revenues from contracts accounted for as derivatives under ASC 815
(1)
Ethanol
1,522,215
329,768
—
1,851,983
Distillers grains
252,694
28,630
—
281,324
Renewable corn oil
136,671
3,346
—
140,017
Other
7,529
14,970
—
22,499
Intersegment revenues
—
25,406
(25,406)
—
Total revenues from contracts accounted for as derivatives
1,919,109
402,120
(25,406)
2,295,823
Total Revenues
$
2,067,089 $
421,107 $
(29,400) $
2,458,796
F-17
Twelve Months Ended December 31, 2023
Ethanol
Production
Agribusiness &
Energy Services
Eliminations
Total
Revenues
Revenues from contracts with customers under ASC 606
Ethanol
$
— $
— $
— $
—
Distillers grains
85,474
—
—
85,474
Renewable corn oil
—
—
—
—
Other
35,222
15,593
—
50,815
Intersegment revenues
4,555
239
(4,794)
—
Total revenues from contracts with customers
125,251
15,832
(4,794)
136,289
Revenues from contracts accounted for as derivatives under ASC 815
(1)
Ethanol
2,117,296
388,764
—
2,506,060
Distillers grains
377,357
34,818
—
412,175
Renewable corn oil
179,424
8,048
—
187,472
Other
25,213
28,534
—
53,747
Intersegment revenues
—
24,907
(24,907)
—
Total revenues from contracts accounted for as derivatives
2,699,290
485,071
(24,907)
3,159,454
Total Revenues
$
2,824,541 $
500,903 $
(29,701) $
3,295,743
(1)
Revenues from contracts accounted for as derivatives represent physically settled derivative sales that are outside the scope of ASC 606.
Major Customer
Revenues from Customer A represented 44% of total revenues for the year ended December 31, 2025, which are
recorded within the ethanol production segment. Revenues from Customer B represented 13% of total revenues for the year
ended December 31, 2024, which are recorded within the ethanol production segment. Revenues from Customer B and
Customer C represented 15% and 10% of total revenues for the year ended December 31, 2023, respectively, which are
recorded within the ethanol production segment.
Payment Terms
The company has standard payment terms, which vary depending upon the nature of the services provided, with the
majority falling within 10 to 30 days after transfer of control or completion of services. In instances where the timing of
revenue recognition differs from the timing of invoicing, the company has determined that contracts generally do not include
a significant financing component.
Contract Liabilities
The company records unearned revenue when consideration is received, or such consideration is unconditionally due,
from a customer prior to transferring goods or services to the customer under the terms of service agreements. Unearned
revenue from service agreements, which represents a contract liability, is recorded for fees that have been charged to the
customer prior to the completion of performance obligations. Unearned revenue is generally recognized in the subsequent
period and is not material to the company. The company expects to recognize all of the unearned revenue associated with
service agreements as of December 31, 2025 when the services are provided.
4. MERGER AND DISPOSITIONS
Proventus LLC Disposition
On May 31, 2025, the company completed the sale of its 75% interest in Proventus LLC for net proceeds of $0.4 million.
The company recorded a pretax loss on the sale of $4.0 million during year ended December 31, 2025 within gain on sale of
assets, net on the consolidated statements of operations. Net assets sold at closing, consisting of property and equipment,
totaled $9.0 million. As part of the transaction, the company removed $4.5 million of non-controlling interest in Proventus
LLC, which was included in the calculation of the pretax loss disclosed above.
F-18
GP Turnkey Tharaldson LLC Disposition
On June 30, 2025, the company sold its 50% investment in GP Turnkey Tharaldson LLC. Proceeds from the disposal
were $24.3 million. The balance of the equity method investment on the date of the disposal was $51.2 million. A pretax loss
of $26.9 million was recorded during year ended December 31, 2025 within loss from equity method investees, net of income
taxes on the consolidated statements of operations.
Green Plains Obion LLC Disposition
On August 27, 2025, Green Plains Inc. announced that its wholly owned subsidiary, Green Plains Obion LLC, entered
into an asset purchase agreement for the sale of the ethanol plant located in Rives, Tennessee, to POET Biorefining - Obion,
LLC. On September 25, 2025, the company closed on the sale and received proceeds of $170 million plus related working
capital of $9.5 million (the “Obion Transaction”). A gain of $35.8 million was recorded in gain on sale of assets, net on the
consolidated statements of operations. The proceeds from the sale were used to repay the outstanding balance of the junior
secured mezzanine notes due 2026 and to supplement corporate liquidity.
The company incurred transaction costs of $5.2 million related to the Obion Transaction during year ended
December 31, 2025. These costs consisted primarily of financial advisory services, legal services and other professional fees,
and were recorded as a reduction of gain on sale of assets, net.
The assets sold and liabilities transferred as a result of the Obion Transaction were as follows (in thousands):
Amounts of Identifiable Assets Disposed and Liabilities Relinquished
Inventories
$
19,529
Prepaid expenses and other
21
Derivative financial instruments
25
Property and equipment
127,088
Operating lease right-of-use assets
3,739
Accounts payable
(5,485)
Accrued and other liabilities
(2,495)
Operating lease current liabilities
(1,687)
Operating lease long-term liabilities
(2,052)
Debt
(657)
Total identifiable net assets disposed
$
138,026
Green Plains Partners Merger
On January 9, 2024, the transactions contemplated by the Merger Agreement were completed and the company issued
approximately 4.7 million shares of common stock to acquire all of the publicly held common units of the partnership not
already owned by the company prior to the Merger at a fixed exchange ratio of 0.405 shares of the company's common stock,
par value $0.001 per share, along with $2.50 of cash consideration for each partnership common unit. The total consideration
as a result of the Merger was $143.1 million, which was comprised of $29.2 million in cash and $113.9 million of common
stock exchanged. As a result of the Merger, the partnership's common units are no longer publicly traded.
The interests in the partnership owned by the company and its subsidiaries remained outstanding as limited partner
interests in the surviving entity until the partnership was dissolved in the fourth quarter of 2024.
Since the company controlled the partnership prior to the Merger and continued to control the partnership after the
Merger, the company accounted for the change in its ownership interest in the partnership as an equity transaction during the
year ended December 31, 2024, which is reflected as a reduction of non-controlling interest with a corresponding increase to
common stock and additional paid-in capital. No gain or loss was recognized in the consolidated statements of operations as a
result of the Merger.
Prior to the effective time of the Merger on January 9, 2024, public unitholders owned a 49.2% limited partner interest,
F-19
the company owned a 48.8% limited partner interest and a 2.0% general partner interest in the partnership. The earnings of
the partnership that were attributed to its common units held by the public for the year ended December 31, 2023 are
reflected in net income attributable to non-controlling interest in the consolidated statements of operations. In 2024, the non-
controlling interest attributed to the partnership common units held by the public of $133.8 million were recorded as a
reduction of non-controlling interest with a corresponding increase to additional paid-in capital.
The company incurred transaction costs of $5.5 million related to the Merger during the year ended December 31, 2024
and $2.0 million during the year ended December 31, 2023. These costs were directly related to the Merger consisting
primarily of financial advisory services, legal services and other professional fees, and were recorded as an offset to the
issuance of common stock within additional paid-in capital.
Disposition of Birmingham Terminal
On September 30, 2024, the company completed the sale of the terminal located in Birmingham, Alabama and certain
related assets and transfer of liabilities (the "Birmingham Transaction") for a sale price of $47.5 million, plus working capital
of $1.2 million. The company recorded a pretax gain on the sale of $30.7 million. The proceeds from the sale were used to
repay the outstanding balance of the Green Plains Partners term loan due July 20, 2026.
The assets sold and liabilities transferred of the Birmingham Transaction at closing on September 30, 2024 were as
follows (in thousands):
Amounts of Identifiable Assets Disposed and Liabilities Relinquished
Prepaid expenses and other
1,209
Property and equipment
7,012
Operating lease right-of-use assets
2,208
Goodwill
10,598
Operating lease current liabilities
(427)
Operating lease long-term liabilities
(2,312)
Other liabilities
(556)
Total identifiable net assets disposed
$
17,732
Disposition of the Atkinson Ethanol Plant
On September 7, 2023, the company completed the sale of the plant located in Atkinson, Nebraska and certain related
assets and transfer of liabilities ("the Atkinson Transaction") for a sale price of $22.9 million, plus working capital of $1.1
million. Correspondingly, the company entered into a separate asset purchase agreement with the partnership for $2.1 million
to acquire the storage assets and the associated railcar operating leases. The divested assets were reported within the
company’s ethanol production, agribusiness and energy services and partnership segments. The company recorded a pretax
gain on the sale of the Atkinson plant of $4.1 million recorded within corporate activities.
F-20
The assets sold and liabilities transferred of the Atkinson plant at closing on September 7, 2023 were as follows: (in
thousands):
Amounts of Identifiable Assets Disposed and Liabilities Relinquished
Inventories
$
3,164
Prepaid expenses and other
423
Property, plant and equipment
15,199
Operating lease right-of-use assets
3,428
Accrued and other liabilities
(162)
Operating lease current liabilities
(1,332)
Operating lease long-term liabilities
(2,096)
Other liabilities
(189)
Total identifiable net assets disposed
$
18,435
5. FAIR VALUE DISCLOSURES
The following methods, assumptions and valuation techniques were used in estimating the fair value of the company’s
financial instruments:
Level 1 – unadjusted quoted prices in active markets for identical assets or liabilities the company can access at the
measurement date.
Level 2 – directly or indirectly observable inputs such as quoted prices for similar assets or liabilities in active markets
other than quoted prices included within Level 1, quoted prices for identical or similar assets in markets that are not active,
and other inputs that are observable or can be substantially corroborated by observable market data through correlation or
other means. Fair value hedged inventories in the agribusiness and energy services segment as well as forward commodity
purchase and sale contracts are valued at nearby futures values, plus or minus nearby basis values, which represent
differences in local markets including transportation or commodity quality or grade differences.
Level 3 – unobservable inputs that are supported by little or no market activity and comprise a significant component of
the fair value of the assets or liabilities.
Derivative contracts include exchange-traded commodity futures and options contracts and forward commodity purchase
and sale contracts. Exchange-traded futures and options contracts are valued based on unadjusted quoted prices in active
markets and are classified in Level 1. The majority of the company’s exchange-traded futures and options contracts are cash-
settled on a daily basis.
F-21
There have been no changes in valuation techniques and inputs used in measuring fair value. The company’s assets and
liabilities by level are as follows (in thousands):
Fair Value Measurements at December 31, 2025
Quoted Prices in
Active Markets
for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Unobservable
Inputs
(Level 3)
Total
Assets
Cash and cash equivalents
$
182,319 $
— $
— $
182,319
Restricted cash
47,813
—
—
47,813
Inventories carried at market
—
24,736
—
24,736
Derivative financial instruments - assets
—
6,927
—
6,927
Property and equipment, net of accumulated
depreciation and amortization (1)
—
—
2,000
2,000
Total assets measured at fair value
$
230,132 $
31,663 $
2,000 $
263,795
Liabilities
Accounts payable (2)
$
— $
28,598 $
— $
28,598
Derivative financial instruments - liabilities
—
7,901
—
7,901
Other liabilities
—
1
—
1
Total liabilities measured at fair value
$
— $
36,500 $
— $
36,500
Fair Value Measurements at December 31, 2024
Quoted Prices in
Active Markets
for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Unobservable
Inputs
(Level 3)
Total
Assets
Cash and cash equivalents
$
173,041 $
— $
— $
173,041
Restricted cash
36,354
—
—
36,354
Inventories carried at market
—
48,500
—
48,500
Derivative financial instruments - assets
—
10,154
—
10,154
Total assets measured at fair value
$
209,395 $
58,654 $
— $
268,049
Liabilities
Accounts payable (2)
$
— $
23,208 $
— $
23,208
Accrued and other liabilities (3)
—
2,094
—
2,094
Derivative financial instruments - liabilities
—
4,791
—
4,791
Other liabilities (3)
—
979
—
979
Total liabilities measured at fair value
$
— $
31,072 $
— $
31,072
(1)
Property and equipment, net of accumulated depreciation and amortization includes $2.0 million of assets held for sale at December 31, 2025.
(2)
Accounts payable is generally stated at historical amounts with the exception of $28.6 million and $23.2 million at December 31, 2025 and 2024,
respectively, related to certain delivered inventory for which the payable fluctuates based on changes in commodity prices. These payables are
hybrid financial instruments for which the company has elected the fair value option.
(3)
As of December 31, 2024, accrued and other liabilities includes $2.1 million and other liabilities includes $1.0 million of consideration related to
potential earn-out payments recorded at fair value.
F-22
The fair value of the company’s debt was approximately $387.8 million compared with a book value of $399.5 million at
December 31, 2025. The fair value of the company’s debt was approximately $518.6 million compared with a book value of
$575.4 million at December 31, 2024. The company estimated the fair value of its outstanding debt using Level 2 inputs. The
company believes the fair value of its accounts receivable approximated book value, which was $74.4 million and $94.9
million at December 31, 2025 and 2024, respectively.
The fair values of tangible assets and goodwill acquired represent Level 3 measurements which were derived using a
combination of the income approach, market approach and cost approach for the specific assets or liabilities being valued.
6. SEGMENT INFORMATION
The company reports 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 and
renewable corn oil 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.
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, as well as gain on sale of assets, net,
and restructuring costs.
During the normal course of business, the operating segments conduct business with each other. For example, the
agribusiness and energy services segment procures grain and natural gas and sells products, including ethanol, distillers
grains, Ultra-High Protein and renewable corn oil for the 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 the company’s consolidated
results since the revenues and corresponding costs are eliminated.
The Chief Operating Decision Maker ("CODM") for the company is the Chief Executive Officer. The CODM utilizes
EBITDA to assess segment performance, which is derived from revenue less cost of goods sold and selling, general and
administrative expenses. The CODM manages and allocates resources to the operations of the Company's two segments. This
enables the CEO to assess the Company’s overall level of available resources and determine how best to deploy these
resources for capital expenditure, research and development projects, and other strategic opportunities that are in line with
our long-term strategic goals. The CODM is regularly provided with consolidated expense information or forecasted expense
information for the applicable reportable segment.
The following tables set forth certain financial data for the company’s operating segments (in thousands):
Year Ended December 31,
2025
2024
2023
Revenues
Ethanol production
Revenues from external customers
$
1,900,999 $
2,063,382 $
2,819,986
Intersegment revenues
859
3,707
4,555
Total segment revenues
1,901,858
2,067,089
2,824,541
Agribusiness and energy services
Revenues from external customers
190,681
395,414
475,757
Intersegment revenues
22,662
25,693
25,146
Total segment revenues
213,343
421,107
500,903
Revenues including intersegment activity
2,115,201
2,488,196
3,325,444
Intersegment eliminations
(23,521)
(29,400)
(29,701)
$
2,091,680 $
2,458,796 $
3,295,743
Refer to Note 3 – Revenue, for further disaggregation of revenue by operating segment.
F-23
Year Ended December 31,
2025
2024
2023
Cost of goods sold
Ethanol production
$
1,804,279 $
1,983,460 $
2,705,917
Agribusiness and energy services
173,996
374,286
454,776
Intersegment eliminations
(23,521)
(29,400)
(29,701)
$
1,954,754 $
2,328,346 $
3,130,992
Year Ended December 31,
2025
2024
2023
Gross margin
Ethanol production (1)(2)
$
97,579 $
83,629 $
118,624
Agribusiness and energy services
39,347
46,821
46,127
$
136,926 $
130,450 $
164,751
Year Ended December 31,
2025
2024
2023
Depreciation and amortization
Ethanol production
$
90,553 $
82,784 $
92,712
Agribusiness and energy services (3)
4,741
2,185
2,360
Corporate activities (4)
3,140
5,618
3,172
$
98,434 $
90,587 $
98,244
Year Ended December 31,
2025
2024
2023
Operating income (loss)
Ethanol production (1)(2)(5)
$
(55,482) $
(40,758) $
(19,958)
Agribusiness and energy services (3)
20,660
28,156
28,100
Corporate activities (4)(6)(7)
(32,426)
(34,857)
(69,720)
$
(67,248) $
(47,459) $
(61,578)
(1)
Ethanol production includes margins from a one-time sale of accumulated RINs of $22.6 million for the year ended December 31, 2025.
(2)
Ethanol production includes an inventory lower of cost or net realizable value adjustment of $1.5 million, $2.1 million, and $2.6 million for the
years ended December 31, 2025, 2024, and 2023, respectively.
(3)
Depreciation and amortization for agribusiness and energy services includes impairment of property and equipment of $3.1 million for the year
ended December 31, 2025.
(4)
Depreciation and amortization for corporate activities includes impairment of a research and development technology intangible asset of $3.5
million for the year ended December 31, 2024.
(5)
Ethanol production includes impairment of assets held for sale of $14.6 million for the year ended December 31, 2025.
(6)
Corporate activities include $16.1 million of restructuring costs for the year ended December 31, 2025 as a result of the company's cost reduction
initiative, including severance related to the departure of its former CEO.
(7)
Corporate activities for the years ended December 31, 2025 and 2024 include a $31.5 million and $30.7 million gain on sale of assets, net,
respectively.
F-24
During the year ended December 31, 2025, the company incurred restructuring costs related to severance, stock based
compensation and other charges as a result of cost reduction initiatives that were recorded within the following line items in
the consolidated statements of operations (in thousands):
Year Ended December 31, 2025
Ethanol
production
Agribusiness and
energy services
Corporate
activities
Subtotal
Cost of goods sold
$
2,373
710
— $
3,083
Selling, general and administrative
480
2,050
16,059
18,589
Other, net
223
941
1,505
2,669
Total restructuring costs
$
3,076
3,701
17,564 $
24,341
The following tables reconcile EBITDA, our segment measure of profit or loss, to net loss (in thousands). 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.
Year Ended December 31, 2025
Ethanol
production
Agribusiness and
energy services
Subtotal
EBITDA
$
33,247 $
25,661 $
58,908
Depreciation and amortization
(90,553)
(4,741)
(95,294)
Interest expense
(55,342)
(5,990)
(61,332)
Subtotal
$
(112,648) $
14,930 $
(97,718)
Unallocated corporate expenses (1)
(75,701)
Income tax benefit, net of equity method income taxes
52,419
Net loss
$
(121,000)
Year Ended December 31, 2024
Ethanol
production
Agribusiness and
energy services
Subtotal
EBITDA
$
39,645 $
31,935 $
71,580
Depreciation and amortization
(82,784)
(2,185)
(84,969)
Interest expense
(22,056)
(4,722)
(26,778)
Subtotal
$
(65,195) $
25,028 $
(40,167)
Unallocated corporate expenses (1)
(35,869)
Income tax expense, net of equity method income taxes
(5,153)
Net loss
$
(81,189)
Year Ended December 31, 2023
Ethanol
production
Agribusiness and
energy services
Subtotal
EBITDA
$
78,561 $
31,689 $
110,250
Depreciation and amortization
(92,712)
(2,360)
(95,072)
Interest expense
(23,545)
(7,723)
(31,268)
Subtotal
$
(37,696) $
21,606 $
(16,090)
Unallocated corporate expenses (1)
(65,826)
Income tax benefit, net of equity method income taxes
5,617
Net loss
$
(76,299)
F-25
(1)
Corporate expenses include selling, general administrative expenses, gain on sale of assets, net, depreciation and amortization, and interest
expense, and during 2025 includes restructuring costs related to cost reduction initiatives and the departure of former CEO as well as losses on
sale of equity method investment.
The following table sets forth capital expenditures by operating segment (in thousands):
Year Ended December 31,
2025
2024
2023
Capital expenditures
Ethanol production
$
36,718 $
89,230 $
107,468
Agribusiness and energy services
164
833
512
Corporate activities
317
5,021
494
$
37,199 $
95,084 $
108,474
The following table sets forth total assets by operating segment (in thousands):
Year Ended December 31,
2025
2024
Total assets (1)
Ethanol production
$
1,133,246 $
1,234,635
Agribusiness and energy services
278,222
412,006
Corporate assets
173,481
143,716
Intersegment eliminations
(6,553)
(8,183)
$
1,578,396 $
1,782,174
(1)
Asset balances by segment exclude intercompany balances.
F-26
7. INVENTORIES
Inventories are carried at the lower of average cost or net realizable value, except fair-value hedged inventories. As of
December 31, 2025 and 2024, respectively, the company recorded a $1.5 million and $2.1 million lower of cost or net
realizable value inventory adjustment associated with finished goods in cost of goods sold within the ethanol production
segment.
The components of inventories are as follows (in thousands):
December 31,
2025
2024
Finished goods
$
24,891 $
72,863
Commodities held for sale
24,736
48,500
Raw materials
26,650
37,334
Work-in-process
9,597
13,569
Supplies and parts
62,221
55,178
$
148,095 $
227,444
8. PROPERTY AND EQUIPMENT
The components of property and equipment are as follows (in thousands):
December 31,
2025
2024
Plant equipment
$
1,173,964 $
1,200,795
Buildings and improvements
235,265
218,660
Land and improvements
94,045
107,543
Railroad track and equipment
21,768
32,137
Construction-in-progress
39,491
174,151
Computer hardware and software
30,516
27,829
Office furniture and equipment
2,934
3,422
Leasehold improvements and other
40,986
27,516
Total property and equipment
1,638,969
1,792,053
Less: accumulated depreciation and amortization
(681,713)
(749,593)
Property and equipment, net
$
957,256 $
1,042,460
Interest capitalized during the years ended December 31, 2025, 2024 and 2023 totaled $4.4 million, $4.4 million and
$3.6 million, respectively.
9. GOODWILL AND INTANGIBLE ASSETS
Goodwill
The company has one reporting unit to which goodwill was assigned. We are required to perform impairment tests
related to our goodwill annually, which we perform as of October 1, or if an indicator of impairment occurs. The company
performed its annual goodwill assessments as of October 1, 2025 and 2024 using qualitative assessments, which resulted in
no indication of goodwill impairment.
On September 30, 2024, goodwill of $10.6 million was disposed of in the Birmingham Transaction, which previously
was recorded within the ethanol production segment. The carrying amount of goodwill attributable to the ethanol production
segment for the years ended December 31, 2025 and 2024 was $18.5 million. The company records goodwill within other
assets on the consolidated balance sheets.
F-27
Intangible Assets
The company recognized certain intangible assets in connection with the FQT acquisition during the fourth quarter of
2020. The components of the intangible assets are as follows (in thousands):
December 31,
2025
2024
Customer relationships and backlog
$
17,628 $
17,628
Intellectual property
9,700
9,700
Trade name
1,300
1,300
Total
28,628
28,628
Accumulated amortization
(18,151)
(15,962)
Total intangible assets, net
$
10,477 $
12,666
Weighted average remaining amortization period
7.9 years
8.9 years
The company recognized $2.2 million, $2.5 million, and $2.8 million of amortization expense associated with these
intangible assets during the years ended December 31, 2025, 2024 and 2023, respectively. The company expects estimated
amortization expense of $2.0 million, $1.8 million, $1.6 million, $1.5 million and $1.3 million for the years ended December
31, 2026, 2027, 2028, 2029 and 2030, respectively, as well as $2.3 million thereafter. The company’s intangible assets are
recorded within other assets on the consolidated balance sheets.
10. DERIVATIVE FINANCIAL INSTRUMENTS
At December 31, 2025, the company’s consolidated balance sheet reflected unrealized losses of $0.6 million, net of tax,
in accumulated other comprehensive income. The company expects these items will be reclassified as operating income over
the next 12 months as a result of hedged transactions that are forecasted to occur. The amount realized in operating income
will differ as commodity prices change.
Fair Values of Derivative Instruments
The fair values of the company’s derivative financial instruments and the line items on the consolidated balance sheets
where they are reported are as follows (in thousands):
Asset Derivatives'
Fair Value at December 31,
Liability Derivatives'
Fair Value at December 31,
2025
2024
2025
2024
Derivative financial instruments - forwards
$
6,927 (1) $
10,154
$
7,901
$
4,791 (2)
Other liabilities
—
—
1
15
Total
$
6,927
$
10,154
$
7,902
$
4,806
(1)
At December 31, 2025, derivative financial instruments, as reflected on the balance sheet, includes net unrealized gains on exchange-traded
futures and options contracts of $4.6 million, which include $0.6 million of net unrealized gains on derivative financial instruments designated as
cash flow hedging instruments, $1.1 million of net unrealized gains on derivative financial instruments designated as fair value hedging
instruments and the balance representing economic hedges.
(2)
At December 31, 2024, derivative financial instruments, as reflected on the balance sheet, includes net unrealized losses on exchange-traded
futures and options contracts of $4.7 million, which include $0.5 million of net unrealized gains on derivative financial instruments designated as
cash flow hedging instruments, $3.0 million of unrealized losses on derivative financial instruments designated as fair value hedging instruments,
and the balance representing economic hedges.
Refer to Note 5 - Fair Value Disclosures, which contains fair value information related to derivative financial
instruments.
F-28
Effect of Derivative Instruments on Consolidated Balance Sheets, Consolidated Statements of Operations and Consolidated
Statements of Comprehensive Loss
The gains or losses recognized in income and other comprehensive income related to the company’s derivative financial
instruments and the line items on the consolidated financial statements where they are reported are as follows (in thousands):
Location of Gain (Loss) Reclassified from
Accumulated Other Comprehensive Income into Income
Amount of Gain (Loss) Reclassified from
Accumulated Other Comprehensive Income
into Income
Year Ended December 31,
2025
2024
2023
Revenues
$
(2,355) $
9,832 $
2,482
Cost of goods sold
(7,682)
(23,270)
(25,003)
Net loss recognized in loss before income taxes
$
(10,037) $
(13,438) $
(22,521)
Gain (Loss) Recognized in
Other Comprehensive Income on Derivatives
Amount of Gain (Loss) Recognized in Other
Comprehensive Income on Derivatives
Year Ended December 31,
2025
2024
2023
Commodity Contracts
$
(12,164) $
(8,001) $
8,369
A portion of the company's derivative instruments are considered economic hedges and as such are not designated as
hedging instruments. The company uses exchange-traded futures and options contracts to manage its net position of product
inventories and forward cash purchase and sales contracts to reduce price risk caused by market fluctuations. Derivatives,
including exchange traded contracts and forward commodity purchase or sale contracts, and inventories of certain
agricultural products, which include amounts acquired under deferred pricing contracts, are stated at fair value. Fair value
estimates are based on exchange-quoted prices, adjusted as appropriate for regional location basis value, which represent
differences in local markets including transportation as well as quality or grade differences.
Derivatives Not Designated
as Hedging Instruments
Location of Gain (Loss)
Recognized in
Income on Derivatives
Amount of Gain (Loss) Recognized in
Income on Derivatives
Year Ended December 31,
2025
2024
2023
Exchange-traded futures and
options
Revenues
$
(10,176) $
4,246 $
(2,552)
Forwards
Revenues
(402)
(4,446)
4,842
Exchange-traded futures and
options
Cost of goods sold
5,067
24,045
45,065
Forwards
Cost of goods sold
(2,317)
5,442
(4,265)
Net gain (loss) recognized in loss before income taxes
$
(7,828) $
29,287 $
43,090
F-29
The following amounts were recorded on the consolidated balance sheets related to cumulative basis adjustments for the
fair value hedged items (in thousands):
December 31, 2025
December 31, 2024
Line Item in the
Consolidated Balance Sheet
in Which the Hedged Item
is Included
Carrying Amount
of the Hedged
Assets
Cumulative Amount
of Fair Value
Hedging
Adjustment
Included in the
Carrying Amount of
the Hedged Assets
Carrying Amount
of the Hedged
Assets
Cumulative Amount
of Fair Value
Hedging
Adjustment
Included in the
Carrying Amount of
the Hedged Assets
Inventories
$
24,736 $
(8,938) $
48,500 $
8,166
Effect of Cash Flow and Fair Value Hedge Accounting on the Statements of Operations
Location and Amount of Gain (Loss)
Recognized in Income on Cash Flow and
Fair Value Hedging Relationships for the
Year Ended December 31, 2025
Revenue
Cost of
Goods Sold
Gain (loss) on cash flow hedging relationships
Commodity contracts
Amount of gain (loss) on exchange-traded futures reclassified from
accumulated other comprehensive income into income
$
(2,355) $
(7,682)
Gain (loss) on fair value hedging relationships
Commodity contracts
Fair value hedged inventories
—
3,339
Exchange-traded futures designated as hedging instruments
—
(1,171)
Total amounts of income and expense line items presented in the
consolidated statement of operations in which the effects of cash flow or
fair value hedges are recorded
$
(2,355) $
(5,514)
F-30
Location and Amount of Gain (Loss)
Recognized in Income on Cash Flow and
Fair Value Hedging Relationships for the
Year Ended December 31, 2024
Revenue
Cost of
Goods Sold
Gain (loss) on cash flow hedging relationships
Commodity contracts
Amount of gain (loss) on exchange traded futures reclassified from
accumulated other comprehensive income into income
$
9,832 $
(23,270)
Gain (loss) on fair value hedging relationships
Commodity contracts
Fair value hedged inventories
—
6,398
Exchange-traded futures designated as hedging instruments
—
(6,039)
Total amounts of income and expense line items presented in the
consolidated statement of operations in which the effects of cash flow or
fair value hedges are recorded
$
9,832 $
(22,911)
Location and Amount of Gain (Loss)
Recognized in Income on Cash Flow and
Fair Value Hedging Relationships for the
Year Ended December 31, 2023
Revenue
Cost of
Goods Sold
Gain (loss) on cash flow hedging relationships
Commodity contracts
Amount of gain (loss) on exchange-traded futures reclassified from
accumulated other comprehensive income into income
$
2,482 $
(25,003)
Gain (loss) on fair value hedging relationships
Commodity contracts
Fair value hedged inventories
—
(11,657)
Exchange-traded futures designated as hedging instruments
—
14,417
Total amounts of income and expense line items presented in the
consolidated statement of operations in which the effects of cash flow or
fair value hedges are recorded
$
2,482 $
(22,243)
F-31
The notional volume of open commodity derivative positions as of December 31, 2025 are as follows (in thousands):
Exchange-Traded (1)
Non-Exchange-Traded (2)
Derivative
Instruments
Net Long & (Short)
Long
(Short)
Unit of Measure
Commodity
Futures
(7,970)
Bushels
Corn
Futures
28,140 (3)
Bushels
Corn
Futures
(2,975) (4)
Bushels
Corn
Futures
(34,230)
Gallons
Ethanol
Futures
(82,152) (3)
Gallons
Ethanol
Futures
(1,163)
MmBTU
Natural Gas
Futures
2,385 (3)
MmBTU
Natural Gas
Futures
(3,603) (4)
MmBTU
Natural Gas
Futures
(13,680)
Pounds
Soybean Oil
Options
3,953
Pounds
Soybean Oil
Options
983
MmBTU
Natural Gas
Forwards
35,414
—
Bushels
Corn
Forwards
13,433
(212,840)
Gallons
Ethanol
Forwards
38
(220)
Tons
Distillers Grains
Forwards
—
(43,490)
Pounds
Renewable Corn Oil
Forwards
4,962
(552)
MmBTU
Natural Gas
(1)
Notional volume of exchange-traded futures and options are presented on a net long and (short) position basis. Options are presented on a delta-
adjusted basis.
(2)
Notional volume of non-exchange-traded forward physical contracts are presented on a gross long and (short) position basis, including both
fixed-price and basis contracts, for which only the basis portion of the contract price is fixed.
(3)
Notional volume of exchange-traded futures used for cash flow hedges.
(4)
Notional volume of exchange-traded futures used for fair value hedges.
Energy trading contracts that do not involve physical delivery are presented net in revenues on the consolidated
statements of operations. Included in revenues are net gains of $11.9 million, $4.1 million, and $4.8 million for the years
ended December 31, 2025, 2024 and 2023, respectively, on energy trading contracts.
F-32
11. DEBT
The components of long-term debt are as follows (in thousands):
December 31,
2025
2024
Corporate
2.25% convertible notes due 2027 (1)
$
60,000 $
230,000
5.25% convertible notes due 2030 (2)
200,000
—
Green Plains SPE LLC
Junior secured mezzanine notes due 2026 (3)
—
125,000
Green Plains Shenandoah
Term loan due 2035 (4)
70,125
71,625
Green Plains York Carbon Capture
Tallgrass Term loan due 2037
34,523
—
Other
9,842
11,163
Total book value of long-term debt
374,490
437,788
Unamortized debt issuance costs
(8,574)
(3,210)
Less: current maturities of long-term debt
(3,924)
(2,118)
Total long-term debt
$
361,992 $
432,460
(1)
The 2027 Notes had $0.4 million and $2.7 million of unamortized debt issuance costs as of December 31, 2025 and 2024, respectively.
(2)
The 2030 Notes had $8.0 million of unamortized debt issuance costs as of December 31, 2025.
(3)
The junior notes had $0.2 million of unamortized debt issuance costs as of December 31, 2024.
(4)
The loan had $0.2 million and $0.3 million of unamortized debt issuance costs as of December 31, 2025 and 2024, respectively.
Scheduled long-term debt repayments excluding the effects of debt issuance costs, are as follows (in thousands):
Year Ending December 31,
Amount
2026
$
3,924
2027
63,952
2028
4,129
2029
4,339
2030
204,441
Thereafter
93,705
Total
$
374,490
The components of short-term notes payable and other borrowings are as follows (in thousands):
December 31,
2025
2024
Green Plains Finance Company, Green Plains Grain and Green Plains Trade
$350.0 million revolver
$
25,000 $
133,500
Green Plains Commodity Management
$20.0 million hedge line
8,584
7,329
$
33,584 $
140,829
F-33
Corporate Activities
In March 2021, the company issued an aggregate $230.0 million of 2.25% Convertible Senior Notes due 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
2027 Notes are senior, unsecured obligations of the company. The 2027 Notes are convertible, at the option of the holders,
into consideration consisting of, at the company’s election, cash, shares of the company’s common stock, or a combination of
cash and stock (and cash in lieu of fractional shares). However, before September 15, 2026, the 2027 Notes will not be
convertible unless certain conditions are satisfied. The initial conversion rate is 31.6206 shares of the company’s common
stock per $1,000 principal amount of 2027 Notes (equivalent to an initial conversion price of approximately $31.62 per share
of the company’s common stock), representing an approximately 37.5% premium over the offering price of the company’s
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, the company may be obligated to increase the conversion rate for any conversion that occurs
in connection with certain corporate events, including the company’s calling the 2027 Notes for redemption.
On and after March 15, 2024, and prior to the maturity date, the company may redeem, for cash, all, but not less than all,
of the 2027 Notes if the last reported sale price of the company’s common stock equals or exceeds 140% of the applicable
conversion price on (i) at least 20 trading days during a 30 consecutive trading day period ending on the trading day
immediately prior to the date the company delivers notice of the redemption; and (ii) the trading day immediately before the
date of the redemption notice. The redemption price will equal 100% of the principal amount of the 2027 Notes to be
redeemed, plus any accrued and unpaid interest to, but excluding, the redemption date. In addition, upon the occurrence of a
“fundamental change” (as defined in the indenture for the 2027 Notes), holders of the 2027 Notes will have the right, at their
option, to require the company to repurchase their 2027 Notes for cash at a price equal to 100% of the principal amount of the
2027 Notes to be repurchased, plus accrued and unpaid interest to, but excluding, the fundamental change repurchase date.
On October 27, 2025, the company executed separate, privately negotiated exchange agreements with certain of the
holders of its existing 2027 Notes to exchange (or 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”). $200 million in aggregate principal
amount of the 2030 Notes is now outstanding, and $60 million in aggregate principal amount of the 2027 Notes remains
outstanding with existing terms unchanged.
The company used approximately $30 million of the net proceeds from the subscription transactions to repurchase
approximately 2.9 million shares of its common stock from certain holders participating in 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 notes are general senior, 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.
On May 7, 2025, the company entered into a secured $30 million revolving credit facility with Ancora Alternatives LLC,
that matured on July 30, 2025. The facility bore interest at 10% on borrowings and had a 0.5% fee on the unused balance.
Interest and fees were due on the 5th of each month. In conjunction with this facility, the company issued 1,504,140 warrants
to purchase shares of its common stock at an exercise price of 0.01 per share. The fair value of these warrants was initially
recorded as debt issuance costs and has been fully amortized and recorded within interest expense during the year ended
December 31, 2025.
Ethanol Production Segment
On February 9, 2021, Green Plains SPE LLC, a wholly-owned special purpose subsidiary and parent of Green Plains
Obion and Green Plains Mount Vernon, issued $125.0 million of junior secured mezzanine notes due 2026 (the “Junior
Notes”) with BlackRock, a holder of a portion of the company’s common stock.
The Junior Notes originally were scheduled to mature on February 9, 2026 and were secured by a pledge of the
membership interests in and the real property owned by Green Plains Obion and Green Plains Mount Vernon. The proceeds
of the Junior Notes were used to construct Ultra-High Protein processing systems at the Green Plains Obion and Green Plains
F-34
Mount Vernon facilities. The Junior Notes accrued interest at an annual rate of 11.75%.
The Junior Notes were amended on May 7, 2025, which extended the maturity date from February 9, 2026 to May 15,
2026. A $2.5 million amendment fee was added to the balance of the Junior Notes, increasing the amount outstanding to
$127.5 million. The Junior Notes were secured by a pledge of the membership interests in and the real property owned by
Green Plains Obion and Green Plains Mount Vernon. Further, warrants previously issued in conjunction with the Junior
Notes were revised on May 7, 2025, and $7.5 million, the fair value of the revised warrants, was recorded as debt issuance
costs. These costs were to be amortized through May 2026. As of July 31, 2025, the Junior Notes were also secured by a
pledge of the membership interests in, the assets and the real property owned by Green Plains Madison LLC, Green Plains
Superior LLC, Green Plains Fairmont LLC, Green Plains Otter Tail LLC, Green Plains Wood River and Green Plains York
LLC, Green Plains Central City LLC, as well as the assets and membership interests of Fluid Quip Mechanical, LLC.
On August 10, 2025, the Junior Notes were amended to extend the maturity date to September 15, 2026, with an
amendment fee of 2.5%, or $3.2 million, added to the principal balance of the Junior Notes, payable at the maturity date. The
interest rate was increased by 0.5% after the amendment, and subject to an additional 0.5% each quarter on each scheduled
interest payment date. The amendment added certain financial covenant requirements, including restrictions on additional
debt and certain transfer of assets. Also as part of the amendment, the company executed a subscription agreement with
certain funds and accounts under management by BlackRock pursuant to which the company agreed to issue, and certain
funds and accounts under management by BlackRock purchased, 3,250,000 stock warrants at a strike price of $0.01 per share
with a ten year exercise period. The amendment also included the right for such funds and accounts to exchange up to
750,000 warrants for a pro rata share of $6 million of outstanding principal of Junior Notes. The subscription agreement
obligated the company to register for resale the shares of common stock underlying warrants issued to BlackRock. The entire
outstanding principal balance, plus any accrued and unpaid interest was due upon maturity. Green Plains SPE LLC was
required to comply with certain financial covenants regarding minimum liquidity at Green Plains and a maximum aggregate
loan to value. The Junior Notes could have been retired or refinanced after 42 months with no prepayment premium. The
Junior Notes had an unsecured parent guarantee from the company and had certain limitations on distributions, dividends or
loans to the company unless there will not exist any event of default. The amendment to the Junior Notes was determined to
be a substantial change under ASC 470, Debt, and triggered debt extinguishment treatment. In total, a loss on debt
extinguishment of $36.9 million was recorded within interest expense during the year ended December 31, 2025. The loss
includes the write-off of unamortized debt issuance costs at the retirement date of the Junior Notes, the fair value of the
3,250,000 warrants issued on August 10, 2025 and the 2.5% amendment fee. On September 25, 2025, proceeds from the
Obion Transaction were used to fully retire the Junior Notes.
On September 3, 2020, Green Plains Wood River and Green Plains Shenandoah, wholly-owned subsidiaries of the
company, entered into a $75.0 million loan agreement with MetLife Real Estate Lending LLC. The loan matures on
September 1, 2035 and is secured by substantially all of the assets of the Shenandoah facility. During the second quarter of
2024, the agreement was modified to remove the Wood River facility from the assets considered to be secured under the loan
agreement and Green Plains Wood River was removed as a counterparty to the loan agreement. The proceeds from the loan
were used to add MSC™ technology at the Wood River and Shenandoah facilities as well as other capital expenditures.
The loan bears interest at a fixed rate of 5.02%, plus an interest rate premium, subject to quarterly adjustments, of 0.00%
to 1.50% based on the leverage ratio of total funded debt to EBITDA of Shenandoah. Principal payments of $1.5 million per
year began in October 2022. Prepayments were prohibited until September 2024. Financial covenants of the loan agreement
include a minimum loan to value ratio of 50%, a minimum fixed charge coverage ratio of 1.25x, a total debt service reserve
of six months of future principal and interest payments and a minimum working capital requirement at Green Plains of not
less than $0.10 per gallon of nameplate capacity or $90.3 million. The loan is guaranteed by the company and has certain
limitations on distributions, dividends or loans to Green Plains by Shenandoah unless immediately after giving effect to such
action, there will not exist any event of default. At December 31, 2025, the interest rate on the loan was 6.52%.
On and after July 24, 2023, Green Plains York Capture Company LLC, a wholly-owned subsidiary of the company,
entered into a series of agreements with Tallgrass High Plains Carbon Storage, LLC and its affiliates to finance, construct and
operate carbon capture, transportation and sequestration assets associated with the Company’s York, Nebraska ethanol
facility. Under the agreements, Green Plains York Capture Company LLC is 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. As of
December 31, 2025, this project has met criteria for substantial completion and is classified as debt. The total estimated value
of this debt recorded on the balance sheet is $34.5 million. Repayments commenced in January 2026. This debt is secured by
substantially all real and personal property interests associated with the Green Plains York Capture Company LLC. Green
Plains Inc. further supports the obligation through a Parent Guaranty, under which it unconditionally guarantees Green Plains
York Capture Company LLC’s performance and payment obligations. Green Plains York Capture Company LLC may pre-
F-35
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.
The total spend related to the other two Nebraska CCS construction projects has been recorded within carbon equipment
liabilities on the consolidated balance sheets. While fully operational as of December 31, 2025, these two projects did not
reach substantial completion until January of 2026. The amounts presented as carbon equipment liabilities as of
December 31, 2025 will be reclassified and presented as debt on the consolidated balance sheets in January of 2026.
Green Plains Partners had a term loan to fund working capital, capital expenditures and other general partnership
purposes. Interest on the term loan was based on 3-month SOFR plus 8.26%. On September 30, 2024, the proceeds from the
Birmingham Transaction were used to repay the outstanding principal and interest of the loan in full. Prepayments totaling
$56.0 million and $3.0 million were made during the years ended December 31, 2024 and 2023, respectively.
The company also has small equipment financing loans, finance leases on equipment or facilities, and other forms of
debt financing.
Agribusiness and Energy Services Segment
On March 25, 2022, Green Plains Finance Company, Green Plains Grain and Green Plains Trade (collectively, the
“Borrowers”), all wholly owned subsidiaries of the company, together with the company, as guarantor, entered into a five-
year, $350.0 million senior secured sustainability-linked revolving Loan and Security Agreement (the “Facility”) with a
group of financial institutions. This transaction refinanced the separate credit facilities previously held by Green Plains Grain
and Green Plains Trade. The Facility matures on March 25, 2027.
The Facility includes revolving commitments totaling $350.0 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. Additionally, the
applicable margin and commitment fee are subject to certain increases or decreases of up to 0.10% and 0.025%, respectively,
tied to the company’s achievement of certain sustainability criteria, including the reduction of GHG emissions, recordable
incident rate reduction, increased renewable corn oil production and the implementation of technology to produce sustainable
ingredients.
The Facility contains customary affirmative and negative covenants, as well as the following financial covenants to be
calculated as of the last day of any month: the current ratio of the Borrowers shall not be less than 1.00 to 1.00; the collateral
coverage ratio of the Borrowers shall not be less than 1.20 to 1.00; and the debt to capitalization ratio of the company shall
not be greater than 0.60 to 1.00.
The Facility also includes customary events of default, including without limitation, failure to make required payments
of principal or interest, material incorrect representations and warranties, breach of covenants, events of bankruptcy and other
certain matters. The Facility is secured by the working capital assets of the Borrowers and is guaranteed by the company. At
December 31, 2025, the interest rate on the Facility was 7.48%.
Green Plains Commodity Management has an uncommitted revolving credit facility to finance margins related to its
hedging programs, which is secured by cash and securities held in its brokerage accounts. On June 18, 2025, the credit
facility was amended, reducing the $40.0 million borrowing limit to $20.0 million. During the first quarter of 2023, this
revolving credit facility was extended five years to mature on April 30, 2028. Advances are subject to variable interest rates
equal to SOFR plus 1.75%. At December 31, 2025, the interest rate on the facility was 5.46%.
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 December 31, 2025.
F-36
Covenant Compliance
The company was in compliance with its debt covenants as of December 31, 2025.
Restricted Net Assets
At December 31, 2025, there were approximately $36.8 million of net assets at the company’s subsidiaries that could not
be transferred to the parent company in the form of dividends, loans or advances due to restrictions contained in the credit
facilities of these subsidiaries.
12. STOCK-BASED COMPENSATION
The company has an equity incentive plan, which reserved a total of 6.9 million shares of common stock for issuance
pursuant to the plan, of which 1.2 million shares remain available for issuance as of December 31, 2025. The plan provides
for shares, including options to purchase shares of common stock, stock appreciation rights tied to the value of common
stock, restricted stock, performance share awards, and restricted and deferred stock unit awards, to be granted to eligible
employees, non-employee directors and consultants. The company measures stock-based compensation at fair value on the
grant date, with no adjustments for estimated forfeitures. The company records noncash compensation expense related to
equity awards in its consolidated financial statements over the requisite period on a straight-line basis.
Grants under the equity incentive plans may include stock options, stock awards, performance share awards or deferred
stock units:
•
Restricted Stock Awards – Restricted stock awards may be granted to directors and employees that vest immediately
or over a period of time as determined by the compensation committee. Stock awards granted to date vested
immediately and over a period of time, and included sale restrictions. Compensation expense is recognized on the
grant date if fully vested or over the requisite vesting period.
•
Deferred Stock Units – Deferred stock units may be granted to directors and employees that vest immediately or
over a period of time as determined by the compensation committee. Deferred stock units granted to date vest over a
period of time with underlying shares of common stock that are issuable after the vesting date. Compensation
expense is recognized on the grant date if fully vested, or over the requisite vesting period.
•
Performance Share Awards – Performance share awards may be granted to directors and employees that cliff-vest
after a period of time as determined by the compensation committee. Performance share awards granted to date cliff-
vest after a period of time, and include sale restrictions. Compensation expense is recognized over the requisite
vesting period.
•
Stock Options – Stock options may be granted that can be exercised immediately in installments or at a fixed future
date. Certain options are exercisable regardless of employment status while others expire following termination.
Options issued to date could have been exercised immediately or at future vesting dates, and expired five years to
eight years after the grant date. Compensation expense for stock options that vest over time was recognized on a
straight-line basis over the requisite service period.
F-37
Restricted Stock Awards and Deferred Stock Units
The restricted non-vested stock awards and deferred stock units activity for the year ended December 31, 2025 is as
follows:
Non-Vested
Shares and
Deferred
Stock Units
Weighted-
Average
Grant-
Date Fair
Value
Weighted-
Average
Remaining
Vesting Term
(in years)
Non-Vested at December 31, 2024
735,513 $
23.45
Granted
1,146,127
5.74
Forfeited
(187,203)
14.82
Vested
(611,204)
19.76
Non-Vested at December 31, 2025
1,083,233 $
8.28
1.7
Performance Share Awards
On March 10, 2025, March 13, 2024, and March 9, 2023, the Compensation Committee of the Board granted
performance shares to be awarded in the form of common stock to certain participants of the plan. These performance shares
vest based on the level of achievement of certain performance goals, including the incremental value achieved from the
company's carbon, high-protein and clean sugar initiatives, in addition to annual production levels and return on investment
(ROI). Performance shares granted in 2025 and 2024 include certain market-based factors requiring a Monte Carlo valuation
model to estimate the fair value of the performance shares on the date of the grant. The weighted average assumptions used
by the company in applying the Monte Carlo valuation model for performance share grants and related valuation include a
risk-free interest rate of 3.87% and 4.44%, dividend yields of 0%, expected volatility of 55.4% and 54.6%, and closing stock
price on the date of grant of $5.48 and $20.21, resulting in an estimated fair value of $7.08 and $25.23 per share for 2025 and
2024, respectively. Off-cycle awards of performance shares occurred on August 19, 2025. A portion of the off-cycle awards
contained certain market-based factors requiring a Monte Carlo valuation model to estimate the fair value of the performance
shares on the date of the grant. The weighted average assumptions used in applying the Monte Carlo valuation model for off-
cycle performance share awards include a risk free rate of 3.69%, dividend yields of 0%, expected volatility of 58.0%, and
closing price on the date of grant of $8.34, resulting in an estimated fair value of $12.89 per share. Performance shares
granted in 2023 do not contain market-based factors requiring a Monte Carlo valuation model. The performance shares were
granted at a target of 100%, but each performance share can be reduced or increased depending on results for the
performance period. If the company achieves the maximum performance goals, the maximum amount of shares available to
be issued pursuant to the 2025, 2024 and 2023 awards are 922,822 performance shares which represents 200% of the 461,441
performance shares which remain outstanding. The actual number of performance shares that will ultimately vest is based on
the actual performance targets achieved at the end of the performance period. This excludes 69,959 performance shares
granted to the Chief Legal and Administration Officer and Corporate Secretary in 2023, 2024 and 2025, which vested at
100% of target on December 31, 2025 in accordance with the Employment Agreement, as amended.
On March 14, 2022, the Compensation Committee of the Board granted performance shares to be awarded in the form of
common stock to certain participants of the plan. The performance shares were granted at a target of 100%, but each
performance share was reduced or increased depending on results for the performance period. On March 14, 2025, based on
the criteria discussed above, the 2022 performance shares vested at 30%, which resulted in the issuance of 14,259 shares of
common stock.
On February 28, 2025, the company announced the departure of Todd Becker as President and Chief Executive Officer,
effective March 1, 2025. In accordance with his separation agreement, 221,895 of remaining outstanding performance shares
that were granted during 2022, 2023, and 2024 vested immediately at target.
F-38
The non-vested performance share award activity for the year ended December 31, 2025 is as follows:
Performance
Shares
Weighted-
Average
Grant-
Date Fair
Value
Weighted-
Average
Remaining
Vesting Term
(in years)
Non-Vested at December 31, 2024
538,572 $
27.82
Granted
460,656
7.22
Forfeited
(161,671)
23.84
Vested
(376,116)
22.51
Non-Vested at December 31, 2025
461,441 $
12.98
1.8
Green Plains Partners
Green Plains Partners had a long-term incentive plan (LTIP) intended to promote the interests of the partnership, its
general partner and affiliates by providing unit-based incentive compensation awards to employees, consultants and directors
to encourage superior performance. As a result of the Merger, the LTIP units available for issuance were converted to 1.2
million shares available for issuance under the company's equity incentive plan.
Stock-Based Compensation Expense
Compensation costs for the stock-based payment plan during the years ended December 31, 2025, 2024 and 2023, were
approximately $17.1 million, $8.3 million and $13.0 million, respectively. At December 31, 2025, there was $7.5 million of
unrecognized compensation costs from stock-based compensation related to non-vested awards. This compensation is
expected to be recognized over a weighted-average period of approximately 1.9 years. The potential tax benefit related to
stock-based payment is approximately 25.2% of these expenses.
13. EARNINGS PER SHARE
Basic earnings per share, or EPS, is calculated by dividing net income available to common stockholders by the weighted
average number of common shares outstanding during the period.
The company computes diluted EPS by dividing net income on an if-converted basis, adjusted to add back net interest
expense related to the convertible debt instruments, by the weighted average number of common shares outstanding during
the period, adjusted to include the shares that would be issued if the convertible debt instruments were converted to common
shares and the effect of any outstanding dilutive securities.
The basic and diluted EPS are calculated as follows (in thousands):
Year Ended December 31,
2025
2024
2023
Net loss attributable to Green Plains
$
(121,278) $
(82,497) $
(93,384)
Weighted average shares outstanding - basic and diluted
67,496
63,796
58,814
EPS - basic and diluted
$
(1.80) $
(1.29) $
(1.59)
Anti-dilutive weighted-average convertible debt, warrants and stock-based
compensation (1)
9,259
7,696
8,419
(1)
The effect related to the company's convertible debt, warrants and certain stock-based compensation award has been excluded from diluted EPS
for the periods presented as the inclusion of these shares would have been antidilutive.
F-39
14. STOCKHOLDERS’ EQUITY
BlackRock Warrants
During the three months ended March 31, 2021, in connection with certain agreements, the company issued 2,000,000
warrants in a private placement to purchase shares of its common stock. The company entered into an amendment on its
Junior Notes on May 7, 2025, and the warrants ("2029 warrants") were repriced from $22.00 to $0.01 and the maturity date
extended from April 28, 2026 to December 31, 2029. The warrants were revalued on May 7, 2025, and the increase in fair
value was recorded in additional paid-in capital.
On August 10, 2025, in conjunction with extending the maturity date of the Junior Notes, 3,250,000 warrants ("2035
warrants") were issued with an exercise price of $0.01 and a maturity date of August 10, 2035. Of the total, 2,500,000 of
these warrants were equity-based and the fair value of the warrants was recorded in additional paid-in capital, and 750,000
were liability-based and the fair value of warrants was initially recorded in other liabilities.
On August 18, 2025, 1,250,000 of the 2029 warrants and 750,000 of the 2035 warrants were exercised. On September 8,
2025, the remaining 2,500,000 2035 warrants were fully exercised and the fair value of the liability-based warrants was
reclassified from other liabilities to additional paid-in capital. The company recognized $2.0 million of expense due to the
revaluation of liability-based warrants, which was recorded in other, net on the consolidated statements of operations during
the year ended December 31, 2025. On October 3, 2025, the remaining 750,000 of 2029 warrants were exercised.
Ancora Warrants
On May 7, 2025, in connection with a revolving credit facility agreement, the company issued warrants in a private
placement to purchase 1,504,140 shares of its common stock at an exercise price of 0.01 per share and expiration date of May
7, 2035. The company measured the fair value of the warrants as of the issuance date. These warrants were equity-based and
recorded in additional paid-in capital. On August 29, 2025, all of the Ancora warrants were exercised and none remained
outstanding.
Other Warrants
Other warrants issued in 2021 totaling 550,000 have a strike price of 22.00. On December 8, 2025, 275,000 of these
warrants expired, and the other 275,000 warrants expire on February 9, 2026. Of the total, 275,000 of the warrants remain
exercisable and outstanding, are treated as liability-based awards and are valued quarterly using the company’s stock price.
These warrants could potentially dilute basic earnings per share in future periods.
Green Plains Partners Merger
As a result of the Merger, for the year ended December 31, 2024, the company issued approximately 4.7 million shares
of common stock and recorded par value $0.001 per share, paid cash consideration of $29.2 million, extinguished the non-
controlling interest attributed to the partnership common units held by the public of $133.8 million, and recorded transaction
costs of $7.5 million within additional paid-in capital. Refer to Note 4 – Merger and Dispositions included herein for more
information.
Treasury Stock
At December 31, 2025, the company holds 5.7 million shares of its common stock at a cost of $61.5 million. Treasury
stock is recorded at cost and reduces stockholders’ equity in the consolidated balance sheets. When shares are reissued, the
company will use the weighted average cost method for determining the cost basis. The difference between the cost and the
issuance price is added or deducted from additional paid-in capital.
Share Repurchase Program
The company’s board of directors authorized a share repurchase program of up to $200.0 million. Under the program, the
company 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 its
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. On October 27, 2025, in conjunction with the privately negotiated
F-40
exchange and subscription agreements for the 2030 Notes, the company repurchased 2.9 million shares of its common stock
for a total of $30.0 million. The company did not repurchase any shares of common stock during 2024 or 2023. Since
inception, the company has repurchased 10.3 million shares of common stock for approximately $122.8 million under the
program.
Accumulated Other Comprehensive Income (Loss)
Changes in accumulated other comprehensive income (loss) are associated primarily with gains and losses on derivative
financial instruments. Amounts reclassified from accumulated other comprehensive income (loss) are as follows (in
thousands):
Year Ended December 31,
Statements of
Operations
Classification
2025
2024
2023
Gains (losses) on cash flow hedges
Commodity derivatives
$
(2,355) $
9,832 $
2,482
(1)
Commodity derivatives
(7,682)
(23,270)
(25,003)
(2)
Total losses on cash flow hedges
(10,037)
(13,438)
(22,521)
(3)
Income tax benefit
(2,529)
(3,223)
(5,438)
(4)
Amounts reclassified from accumulated other
comprehensive loss
$
(7,508) $
(10,215) $
(17,083)
(1)
Revenues
(2)
Cost of goods sold
(3)
Loss before income taxes and income from equity method investees
(4)
Income tax benefit (expense)
At December 31, 2025 and 2024, the company’s consolidated balance sheets reflected unrealized losses of $0.6 million
and unrealized gains of $1.0 million, net of tax, in accumulated other comprehensive loss, respectively.
15. INCOME TAXES
Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for
the future tax consequences attributable to differences between the carrying amounts of existing assets and liabilities and their
respective tax bases, and net operating loss and tax credit carry-forwards. Deferred tax assets and liabilities are measured
using enacted rates expected to be applicable to taxable income in the years those temporary differences are recovered or
settled. The effect on deferred tax assets and liabilities from a change in tax rates is recognized in income during the period
that includes the enactment date. A valuation allowance is recorded by the company when it is more likely than not that some
portion or all of a deferred tax asset will not be realized.
The IRA was signed into law on August 16, 2022. The IRA includes significant law changes relating to tax, climate
change, energy and health care. The IRA significantly expands clean energy related tax credits and permits more flexibility
for taxpayers to use the credits with direct-pay and transferable credit options.
The OBBB was signed into law on July 4, 2025. The OBBB includes a broad range of tax reform provisions affecting
businesses, including extending and modifying certain key provisions of the Tax Cuts & Jobs Act, and expanding certain IRA
incentives while accelerating the phase-out of others. Important business provisions of the OBBB include reinstatement of
permanent expensing of domestic research and development costs, higher EBITDA cap on the deduction for interest expense
and 100% bonus depreciation. In addition, the OBBB extends the tax credit for Clean Fuel Production under Section 45Z to
December 31, 2029, and leaves credits generated from carbon capture under Section 45Q substantially unchanged. The
company will benefit from the reinstatement of permanent expensing of domestic research and development costs and the
higher EBITDA cap on the deduction for interest expense, as well as the extension of the tax credit for Clean Fuel Production
under Section 45Z to December 31, 2029.
The Section 45Z clean fuel production credit is a general business credit under Section 38 that is allowed with respect to
clean transportation fuel produced domestically after December 31, 2024, and before December 31, 2029. This credit, which
was part of the IRA, and subsequently extended by the OBBB, incentivizes the production of clean fuels at our plants that
F-41
reduce GHG emissions below a CI score of 50. The tax credit is calculated by multiplying the gallons of clean transportation
fuel produced times the CI emission factor times the applicable credit rate per gallon ($0.20 for non-SAF transportation fuel,
or $1.00 if the taxpayer satisfies the prevailing wage requirements under Section 45). The company expects that it is more-
likely-than-not that prevailing wage requirements will be met for 2025 for six facilities and has calculated the credit at the
highest credit rate.
On September 16, 2025, the company entered into an agreement, pursuant to which the company agreed to supply
production tax credits available under Section 45Z to a buyer from the production of the company's ethanol at its Nebraska
facilities between January 1, 2025 and December 31, 2025. On December 10, 2025, the agreement was amended to add
Section 45Z production tax credits produced at three more of the company's facilities. All credits generated during the year
ended December 31, 2025, were sold in accordance with these agreements. The final proceeds are dependent on actual
production and the final CI score at the company's facilities. Based on production and CI scores for the year ended
December 31, 2025, the company recorded an income tax benefit of $54.2 million, net of a valuation allowance, related to
45Z production tax credits. The company expects to benefit from certain energy related tax credits in future years.
On January 9, 2024, the transactions contemplated by the Merger Agreement were completed as described in more detail
in Note 4 – Merger and Dispositions included herein. For income tax purposes, the total consideration given by the company
in exchange for the remaining interest in the partnership, creates a tax basis in the acquired interest. Because the GAAP basis
in the acquired interest is less than the total consideration, a new deferred tax asset was created. The company's valuation
allowance on deferred tax assets increased by a corresponding amount, which did not have a material impact on the
company's consolidated financial statements.
On July 30, 2025 the company settled our federal R&D tax credit audit covering years 2013 through 2018 with the IRS
Independent Office of Appeals. The final settlement was in accordance with the agreement in-principle reached in November
2024. As a result of the settlement, the company released our reserve for unrecognized tax benefits and adjusted our R&D tax
credit carry-forward to reflect the post settlement amount. The settlement did not have a material impact on the company's
consolidated financial statements. The company’s federal income tax returns for the tax years ended December 31, 2022
through 2024 are still subject to audit.
In accordance with ASU 2023-09, income tax expense (benefit) consists of the following (in thousands):
Year Ended
December 31,
2025
Current
Federal
$
1,181
State
58
Foreign
—
Total current
1,239
Deferred
Federal
(53,098)
State
113
Foreign
—
Total deferred
(52,985)
Total income tax expense (benefit)
$
(51,746)
Income tax expense (benefit) consists of the following (in thousands):
Year Ended December 31,
2024
2023
Current
$
2,268 $
1,238
Deferred
3,944
(6,855)
Total income tax expense (benefit)
$
6,212 $
(5,617)
F-42
In accordance with ASU 2023-09, the following table summarizes differences between income tax expense (benefit) at
the statutory federal income tax rate and as presented on the consolidated statements of operations (in thousands):
Year Ended December 31,
2025
Tax expense at federal statutory rate
$
(35,841)
21.0%
State income tax expense, net of federal benefit (1)
231
(0.1)
Foreign tax effects
—
—
Effect of changes in tax laws or rates
—
—
Effect of cross-border taxes
—
—
Tax Credits
Section 45Z production tax credits
(63,180)
37.0%
Changes in valuation allowances
45,595 (26.7)%
Nontaxable or nondeductible items
Stock compensation
2,798
(1.6)%
Other
811
(0.5)%
Changes in unrecognized tax benefits
—
—%
Other adjustments
Deferred tax asset adjustment
(2,487)
1.4%
Other
327
(0.2)%
Income tax expense (benefit)
$
(51,746)
30.3%
(1)
State taxes in Louisiana and New Jersey accumulated to over 50% of the tax effect in this category.
Differences between income tax expense (benefit) at the statutory federal income tax rate and as presented on the
consolidated statements of operations are summarized as follows (in thousands):
Year Ended December 31,
2024
2023
Tax expense at federal statutory rate
$
(14,750) $
(17,293)
State income tax expense (benefit), net of federal benefit
1,123
(662)
Nondeductible compensation
1,388
2,787
Noncontrolling interests
(150)
(3,660)
Dissolution of MLP
23,919
—
R&D tax credit audit agreement in-principle
(232)
—
Increase (decrease) in valuation allowance
(5,491)
15,892
Stock compensation
278
(4,440)
Other
127
1,759
Income tax expense (benefit)
$
6,212 $
(5,617)
F-43
Significant components of deferred tax assets and liabilities are as follows (in thousands):
December 31,
2025
2024
Deferred tax assets
Net operating loss carryforwards - Federal
$
55,667 $
26,104
Net operating loss carryforwards - State
21,474
15,777
Tax credit carryforwards - Federal
74,501
35,098
Tax credit carryforwards - State
370
1,359
Section 174 capitalized expenses
38,849
54,470
Interest expense carryforward
32,756
20,003
Investment in partnerships and joint ventures
4,657
3,807
Inventory valuation
1,178
983
Stock-based compensation
1,811
1,377
Accrued expenses
10,723
7,818
Lease obligations
17,640
18,693
Organizational and start-up costs
331
379
Other
1,658
1,580
Total
261,615
187,448
Valuation allowance
(118,865)
(77,657)
Total deferred tax assets
142,750
109,791
Deferred tax liabilities
Fixed assets
(91,831)
(98,485)
Derivative financial instruments
(1,043)
(78)
Right-of-use assets
(16,039)
(17,081)
Total deferred tax liabilities
(108,913)
(115,644)
Deferred income taxes, net
$
33,837 $
(5,853)
At December 31, 2025, the company has federal research and development credits of $28.5 million which will begin to
expire in 2033 and federal 45Z production tax credits of $40.3 million, which are contracted for sale with a third-party. The
company also has $0.3 million of state credits which will expire, subject to taxable income, beginning in 2026. The company
has federal net operating losses of $55.7 million, which do not have an expiration date and state net operating losses of
$21.5 million, some of which begin expiring in 2026. The company also has a capital loss carry-forward of $1.0 million
which will expire in 2030.
The company has established a valuation allowance against its deferred tax assets due to uncertainty that it will realize
these assets in the future. The valuation allowance on deferred tax assets was recognized as a result of negative evidence,
including cumulative losses in recent years, outweighing the more subjective positive evidence. Management considers
whether it is more likely than not that some or all of the deferred tax assets will be realized, which is dependent on the
generation of future taxable income and other tax attributes during the periods those temporary differences become
deductible. Scheduled reversals of deferred tax liabilities, projected future taxable income, and tax planning strategies are
considered to make this assessment. The company will continue to regularly assess the realizability of deferred tax assets.
Changes in earnings performance and future earnings projections, among other factors, may cause the company to adjust its
valuation allowance on deferred tax assets, which would impact the company’s results of operations in the period it is
determined that these factors have changed.
The company has no unrecognized tax benefits at December 31, 2025. The company had $79.5 million of unrecognized
tax benefits at December 31, 2024. Unrecognized tax benefits were recorded as a reduction of the deferred tax asset
associated with the federal tax credit carryforwards. Interest and penalties associated with uncertain tax positions are accrued
as part of income taxes payable. On July 30, 2025, the company settled our federal R&D tax credit audit covering tax years
F-44
2013 through 2018 with the IRS Independent Office of Appeals. As a result of the settlement, the company released its
reserve for unrecognized tax benefits.
Income taxes paid, net of refunds, were as follows (in thousands):
Year Ended December 31,
2025
Federal
$
76
State
1,692
Foreign
—
Total
$
1,768
State jurisdictions exceeding 5% of total income taxes paid, net of refunds
Texas
$
1,283
New Jersey
109
16. COMMITMENTS AND CONTINGENCIES
Lease Expense
The company leases certain facilities, parcels of land, and equipment, with remaining terms ranging from less than one
year to 11.9 years. The land and facility leases include renewal options. The renewal options are included in the lease term
only for those sites or locations in which they are reasonably certain to be renewed. Equipment renewals are not considered
reasonably certain to be exercised as they typically renew with significantly different underlying terms.
The company may sublease certain of its railcars to third parties on a short-term basis. The subleases are classified as
operating leases, with the associated sublease income being recognized on a straight-line basis over the lease term.
The components of lease expense are as follows (in thousands):
Year Ended December 31,
2025
2024
2023
Lease expense
Operating lease expense
$
29,474 $
29,061 $
27,773
Variable lease expense (benefit) (1)
1,243
1,075
(97)
Total lease expense
$
30,717 $
30,136 $
27,676
(1)
Represents amounts incurred in excess of the minimum payments required for a certain building lease and for the handling and unloading of
railcars for a certain land lease, offset by railcar lease abatements provided by the lessor when railcars are out of service during periods of
maintenance or upgrade.
F-45
Supplemental cash flow information related to operating leases is as follows (in thousands):
Year Ended December 31,
2025
2024
2023
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases
$
29,955 $
29,568 $
27,275
Right-of-use assets obtained in exchange for lease obligations
Operating leases
22,024
25,403
28,471
Right-of-use assets and lease obligations derecognized due to lease
modifications
Right-of-use assets (1)
3,739
2,208
3,428
Lease obligations (1)
3,739
2,739
3,428
(1)
Amounts presented in 2025 are related to the Obion Transaction, amounts in 2024 are related to the Birmingham Transaction, while amounts in
2023 relate to the Atkinson Transaction. Derecognition of right-of-use assets and lease obligations for both dispositions is related to railcar
operating leases.
Supplemental balance sheet information related to operating leases is as follows:
2025
2024
Weighted average remaining lease term
3.8 years
4.0 years
Weighted average discount rate
5.46%
5.36%
Aggregate minimum lease payments under the operating lease agreements for future fiscal years as of December 31,
2025 are as follows (in thousands):
Year Ending December 31,
Amount
2026
$
24,365
2027
20,092
2028
11,618
2029
8,087
2030
4,418
Thereafter
3,738
Total
72,318
Less: Present value discount
(7,113)
Lease liabilities
$
65,205
Other Commitments
As of December 31, 2025, the company had contracted future purchases of grain, ethanol, distillers grains, and natural
gas valued at approximately $202.2 million and future commitments for storage and transportation, valued at approximately
$31.4 million.
The company has entered into contracts with Tallgrass High Plains Carbon Storage, LLC and its affiliates, related to the
construction, development and operation of carbon capture and sequestration projects at our three Nebraska plants. As of
December 31, 2025, one project has met criteria for substantial completion and is classified as debt and the two other projects
are in the final stages and did not reach substantial completion until January of 2026. Payments associated with these
contracts are due monthly over a period of twelve years, commencing after the capture facilities are considered substantially
complete. Amounts due under the contracts are based on the achievement of certain project milestones and are subject to
F-46
termination of all or portions of the contracts. Certain of the future obligations to Tallgrass High Plains Carbon Storage, LLC
are secured by a leasehold deed of trust, security agreement and assignment of rents and leases. As of December 31, 2025, the
company had incurred $104.2 million of accumulated construction costs in relation to the two projects yet to reach substantial
completion, presented as carbon equipment liabilities on the consolidated balance sheets.
Government Assistance
During the year ended December 31, 2023 the company received relief grants of $3.4 million from the USDA related to
the Biofuel Producer Program. The grants received were recorded as other income and the company has no further reporting
or other obligations related to the receipt of these grants.
Legal
The company is currently involved in litigation that has arisen in the ordinary course of business, but does not believe
any pending litigation will have a material adverse effect on its financial position, results of operations or cash flows.
17. EMPLOYEE BENEFIT PLANS
The company offers eligible employees a comprehensive employee benefits plan that includes health, dental, vision, life
and accidental death, short-term disability and long-term disability insurance, and flexible spending accounts. The company
also offers a 401(k) plan enabling eligible employees to save for retirement on a tax-deferred basis up to the limits allowed
under the Internal Revenue Code. Effective January 1, 2025, the company decreased the employer match for employees with
5 years of service from 8% to 6% of eligible employee contributions, the same match for eligible employees with less than 5
years of service. Employee and employer contributions are 100% vested immediately. Employer contributions to the 401(k)
plan for the years ended December 31, 2025, 2024 and 2023 were $3.0 million, $4.5 million and $3.9 million, respectively.
The company contributes to a defined benefit pension plan. Since January 2009, the benefits under the plan were frozen;
however, the company remains obligated to ensure the plan is funded according to its requirements. As of December 31,
2025, the plan’s assets were $4.7 million and liabilities were $4.8 million. At December 31, 2025 and 2024, net liabilities of
$0.1 million and $0.7 million, respectively, were included in other liabilities on the consolidated balance sheets.
18. SUBSEQUENT EVENTS
In January of 2026, the CCS construction projects at the company's Nebraska plants in Wood River and Central City
reached substantial completion, joining the company's York, Nebraska plant which reached substantial completion in
December of 2025. In accordance with the financing agreements for these projects, repayments have commenced in 2026.
Monthly repayments are scheduled to continue for twelve years. Amounts classified as carbon equipment liabilities in the
company's consolidated balance sheets as of December 31, 2025 will be reclassified as debt beginning in January 2026.
Green Plains Inc. 2025 Annual Report
Corporate
Information
Board of Directors
JAMES D. ANDERSON(2),(4),(5)
Chairman
Chief Executive Officer Molycop
FARHA ASLAM(2),(4)
Managing Partner
Crescent House Capital
STEVE FURCICH(2),(5)
Partner
Tillridge Global Agribusiness Fund
CARL GRASSI(3),(5)
Former Chairman
McDonald Hopkins LLC
CHRIS G. OSOWSKI
President and Chief Executive Officer
Green Plains Inc.
BRIAN PETERSON(2),(4)
President and Chief Executive Officer
Whiskey Creek Enterprises
MARTIN SALINAS JR.(1),(3)
Former Chief Financial Officer
Energy Transfer Partners, LP
PATRICK SWEENEY(1),(5)
Director, Portfolio Manager
Ancora Holdings Group LLC
KIMBERLY WAGNER(1),(3)
Managing Partner TBGD Partners
Member of; (1) Audit Committee,
(2) Compensation Committee (3)
Nominating and Governance Committee
(4) Risk Committee (5) Strategic Planning
Committee
Executive Officers
CHRIS G. OSOWSKI
President and Chief Executive Officer
ANN REIS
Chief Financial Officer
TRENT COLLINS
Senior Vice President - Operations
IMRE HAVASI
Senior Vice President - Head of
Trading and Commercial Operation
JAMES F. HERBERT II
Chief Human Resources Officer
RYAN LONEMAN
General Counsel and Corporate
Secretary
Corporate Office
1811 Aksarben Drive
Omaha, NE 68106
402.884.8700
www.gpreinc.com
Investor Relations
WILL JOEKEL
will.joekel@gpreinc.com
Stock Exchange Listing
The Nasdaq Global Market
Stock Ticker Symbol: GPRE
Stock Transfer Agent
Correspondence should be
mailed to:
Computershare
P.O. Box 43006
Providence, RI 02940-3006
Overnight correspondence should
be mailed to:
Computershare
150 Royall Street, Suite 101 Canton,
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Shareholder services:
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Investor CentreTM portal:
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Green Plains Inc.
1811 Aksarben Drive
Omaha, NE 68106
www.gpreinc.com