2024 Biomass Magazine Issue 1 by BBI International

Issue 1, 2024

OPERATION

SEQUESTRATION Restoration Bioproducts’ Biochar Buildout PAGE 20

PLUS: Aemetis’

Approach to Advancing Biofuels PAGE 12

Carbon-Negative Biofuel Pathways PAGE 32

BiomassMagazine.com

BIOMASSMAGAZINE.COM 1

Increase your profits with intelligent solutions Chipping • Conveying • Milling • Screening • Ship loading • Ship unloading • Stacking & Reclaiming • Truck unloading • Wood residue processing bruks-siwertell.com

ISSUE 1 | VOLUME 17

FEATURES 12 PROJECT DEVELOPMENT The Keyes to Success

With crossovers into ethanol, biogas and RNG, sustainable aviation fuel, biodiesel and more, there are common denominators amongst Aemetis’ endeavors: waste utilization and low carbon intensity. By Keith Loria

PAGE 12

COLUMN 04 EDITOR’S NOTE

All Hands (Renewables) on Deck By Anna Simet

06 Climate Challenge Calls for Diverse Solutions By Dylan Chase

07 Utilizing an Asset

Management Partner By Katy Falkenborg

DEPARTMENTS 08 BIOMASS NEWS ROUNDUP 10 SPOTLIGHT: MID-SOUTH ENGINEERING Leading Clients to the Finish Line 11 SPOTLIGHT: PICK HEATERS Choosing Pick Steam Injection

¦ADVERTISER INDEX 34-35 2023 Int’l Biomass Conference & Expo 17

ABMA American Boiler Manufacturers Association

02 31 29

BRUKS Siwertell CSX Transportation Detroit Stoker Company

22 09 14 25 15 18 30 10 23 11 24 37 16 41 19 44

Duragrind Evergreen Engineering Fagus GreCon, Inc. Hurst Boiler & Welding Co. Inc. Intramicron, Inc. KEITH Manufacturing Company KESCO, Inc. Mid-South Engineering Company MoistTech Pick Heaters, Inc. Player Design, Inc. Rawlings Waste Wood Recovery Systems Roeslein & Associates, Inc. Timber Products Inspection/Biomass Energy Laboratories Tri-Mer Corporation Vecoplan LLC

20 BIOCHAR Restore and Revive

Colocated with a pellet plant, a new biochar facility is under construction in Virginia, the carbon credits of which have been purchased by Microsoft. By Katie Schroeder

26 CARBON The Quest to Capture Carbon

Policy, regulation and opportunities in the ethanol and sustainable aviation fuel sectors were main topics of discussion at the National Carbon Capture Conference & Expo. By Anna Simet

CONTRIBUTIONS 32 CARBON Pathways for Carbon-Negative Biomass Fuels

California’s agricultural and forest residues can be transformed into carbon-negative fuels, offering a significant opportunity to reduce emissions. By Anna Redmond and Stefan Unnasch

36 PELLETS Pellet Fuel Essential to Decarbonization Goals

There is already a well-developed strategy that can be implemented today in the transition to a decarbonized future. By William Strauss

38 HYDROGEN Containerized Electrolysers: Enabling Rapid Deployment of SAF Production Facilities The carbon intensity of the single largest-volume raw material in SAF production—hydrogen—is a key consideration for SAF producers. By Lynn Gorman

40 EMISSIONS Catalytic Ceramic Filters for Biomass Power Plant Flue Gas Treatment

Catalytic ceramic filters offer economic, operational and technical advantages to biomass boilers. By Iam Chisem

Biomass Magazine: (USPS No. 5336, ISSN 21690405) Copyright © 2024 by BBI International is published quarterly by BBI International, 308 Second Avenue North, Suite 304, Grand Forks, ND 58203. Four issues per year. Business and Editorial Offices: 308 Second Avenue North, Suite 304, Grand Forks, ND 58203. Accounting and Circulation Offices: BBI International 308 Second Avenue North, Suite 304, Grand Forks, ND 58203. Call (701) 746-8385 to subscribe. Periodicals postage paid at Grand Forks, ND and additional mailing offices. POSTMASTER: Send address changes to Biomass Magazine/Subscriptions, 308 Second Avenue North, Suite 304, Grand Forks, ND 58203.

BIOMASSMAGAZINE.COM 3

¦EDITOR’S NOTE

All Hands (Renewables) on Deck

ANNA SIMET EDITOR

asimet@bbiinternational.com

There’s no snow in most of Minnesota, as of January 1. My kids have been outside riding their bikes and playing basketball over holiday break. While brown Christmases have happened here before, these 50-plus degree temperatures have broken records. Our neighbors to the west in North Dakota are on the tail end of a two-day ice storm; freezing rain crippled the state and closed our headquarters for two days. Trees coated in inches of ice have been giving way to the wind and splitting in two—including several trees my dad planted 30 years ago on our farm. Rain in North Dakota, where I grew up, at the end of December is very unusual. While most of us experiencing this weird weather joke that we don’t mind no snow and warmer temperatures, is it perhaps a subtle indication of things to come if we don’t change course? Throughout the pages of this issue, you’ll find a common theme. Repeated over and over again, in different versions from the authors and those quoted in the stories: We need to do something to stop climate change, and we need to do it now. Through any and all means possible. Gone are the days where different types of renewables are pitted against each other—there is room for all, and we need all hands on deck. As stated in the column by RNG Coalition’s Dylan Chase on page 6, “It is high time we recognize that our near future cannot be wind and solar alone … Nor can our future be electrons versus molecules, NIMBYs versus industry, or left versus right. A truly sustainable future will require a diverse portfolio of sustainable solutions.” In our page-26 feature, “The Quest to Capture Carbon,” I cover discussion had at the National Carbon Capture Conference & Expo. While the programming wasn’t specific toward bioenergy, other biofuels—particularly ethanol and sustainable aviation fuel—were focused on as important parts of the equation in carbon emission mitigation (i.e., capturing and storing ethanol plant emissions via pipeline, bringing down its carbon intensity and qualifying the fuel as a SAF feedstock). While biomass energy carbon capture and storage is very much in its infancy, companies like Drax have begun the charge to deployment. Our other two features, “The Keyes to Success” on page 12 and “Restore and Revive” on page 20, are focused on projects that utilize waste and reduce carbon emissions. In the first, contributing writer Keith Loria interviews Aemetis’ Chairman and CEO Eric McAfee about the company’s project development strategy. Originally working and finding great success in the ethanol space, McAfee tells Loria that he “wanted to do waste—low carbon intensity, low cost, all the benefits of waste feedstock.” And that’s exactly what he and Aemetis have done, through ethanol, biodiesel, renewable natural gas—and soon, sustainable aviation fuel—projects that have continued to evolve to become more efficient and lower in carbon intensity. As for the latter story, staff writer Katie Schroeder chatted with Jeff Waldon, managing partner of Restoration Bioproducts, which is currently constructing a biochar plant adjacent to wood pellet producer Wood Fuel Developers in Waverly, Virginia. Waldon highlights the facility’s feedstock-sourcing strategy—waste streams from the pellet plant and other nearby sources—essentially minimizing feedstock transportation emissions. Pyrolysis gas will be captured and used as a process fuel, and the end product—biochar—is an excellent carbon sequestration medium. The project has already sold its carbon credits to Microsoft, and Waldon is confident the next year will see a wave of activity in projects like this one. He said, “There’s a tremendous amount of interest in this nascent industry. There are all kinds of things going on behind the scenes—there’s a dozen different stealth activities going on. Stay tuned, the announcements I think are going to come fast and furious [in 2024].” On a final note, if you’re one of those soon-to-announce projects, make sure you drop a line our way—we’d love to learn more and help spread the word.

4 BIOMASS MAGAZINE | ISSUE 1, 2024

INDUSTRY EVENTS¦

EDITORIAL

EDITOR Anna Simet asimet@bbiinternational.com ONLINE NEWS EDITOR Erin Voegele evoegele@bbiinternational.com STAFF WRITER Katie Schroeder katie.schroeder@bbiinternational.com

ART

VICE PRESIDENT OF PRODUCTION & DESIGN Jaci Satterlund jsatterlund@bbiinternational.com GRAPHIC DESIGNER Raquel Boushee rboushee@bbiinternational.com

2024 Int’l Biomass Conference & Expo MARCH 4-6, 2024

Greater Richmond Convention Center, Richmond, VA Now in its 17th year, the International Biomass Conference & Expo is expected to bring together more than 900 attendees, 150 exhibitors and 65 speakers from more than 21 countries. It is the largest gathering of biomass professionals and academics in the world. The conference provides relevant content and unparalleled networking opportunities in a dynamic business-to-business environment. In addition to abundant networking opportunities, the largest biomass conference in the world is renowned for its outstanding programming—powered by Biomass Magazine—that maintains a strong focus on commercial-scale biomass production, new technology, and near-term research and development. (866) 746-8385 | www.BiomassConference.com

2024 Int’l Fuel Ethanol Workshop & Expo

PUBLISHING & SALES CEO Joe Bryan jbryan@bbiinternational.com PRESIDENT Tom Bryan tbryan@bbiinternational.com VICE PRESIDENT OF OPERATIONS/MARKETING & SALES John Nelson jnelson@bbiinternational.com SENIOR ACCOUNT MANAGER/ BIOENERGY TEAM LEADER Chip Shereck cshereck@bbiinternational.com ACCOUNT MANAGER Bob Brown bbrown@bbiinternational.com CIRCULATION MANAGER Jessica Tiller jtiller@bbiinternational.com MARKETING & ADVERTISING MANAGER Marla DeFoe mdefoe@bbiinternational.com

JUNE 10-12, 2024

Minneapolis Convention Center, Minneapolis, Minnesota Now in its 40th year, the FEW provides the ethanol industry with cutting-edge content and unparalleled networking opportunities in a dynamic business-to-business environment. As the largest, longest running ethanol conference in the world, the FEW is renowned for its superb programming—powered by Ethanol Producer Magazine —that maintains a strong focus on commercial-scale ethanol production, new technology, and near-term research and development. The event draws more than 2,000 people from over 31 countries and from nearly every ethanol plant in the United States and Canada. (866) 746-8385 | www.FuelEthanolWorkshop.com

2024 North American SAF Conference & Expo SEPTEMBER 11 - SEPTEMBER 12, 2024 Saint Paul Rivercentre, Saint Paul, Minnesota

The North American SAF Conference & Expo, produced by SAF Magazine, in collaboration with the Commercial Aviation Alternative Fuels Initiative (CAAFI) will showcase the latest strategies for aviation fuel decarbonization, solutions for key industry challenges, and highlight the current opportunities for airlines, corporations and fuel producers. The North American SAF Conference & Expo is designed to promote the development and adoption of practical solutions to produce SAF and decarbonize the aviation sector. Exhibitors will connect with attendees and showcase the latest technologies and services currently offered within the industry. During two days of live sessions, attendees will learn from industry experts and gain knowledge to become better informed to guide business decisions as the SAF industry continues to expand. (866) 746-8385 | www.SAFConference.com

Please check our website for upcoming webinars

Please recycle this magazine and remove inserts or samples before recycling TM

www.biomassmagazine.com/pages/webinar

Subscriptions Biomass Magazine is free of charge to everyone with the exception of a shipping and handling charge for anyone outside the United States. To subscribe, visit www.BiomassMagazine.com or you can send your mailing address and payment (checks made out to BBI International) to Biomass Magazine Subscriptions, 308 Second Ave. N., Suite 304, Grand Forks, ND 58203. You can also fax a subscription form to 701-746-5367. Back Issues & Reprints Select back issues are available for $3.95 each, plus shipping. Article reprints are also available for a fee. For more information, contact us at 701-746-8385 or service@ bbiinternational.com. Advertising Biomass Magazine provides a specific topic delivered to a highly targeted audience. We are committed to editorial excellence and high-quality print production. To find out more about Biomass Magazine advertising opportunities, please contact us at 701-746-8385 or service@bbiinternational.com. Letters to the Editor We welcome letters to the editor. Send to Biomass Magazine Letters to the Editor, 308 2nd Ave. N., Suite 304, Grand Forks, ND 58203 or email to asimet@bbiinternational.com. Please include your name, address and phone number. Letters may be edited for clarity and/or space.

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Climate Challenge Calls for Diverse Solutions BY DYLAN CHASE

Whether in boardroom earnings calls, keynote speeches or media editorials, these days I see the same question repeated everywhere: Is the U.S. heading in the right direction on climate policy? Answers to that question vary, but one thing is certain: Concern over how communities, corporate leaders and elected officials are handling climate change has never been more apparent. Most U.S. adults (54%) describe climate change as a “major threat” to our country’s well-being, up from around 44% a decade ago, according to a 2023 survey from Pew Research Center. Some 61% of Americans say that climate change is directly affecting their community. The Biden administration has addressed these concerns by injecting funds into the U.S. decarbonization effort via Build Back Better, the Inflation Reduction Act and other policies. Those federal programs have earmarked hundreds of billions of dollars to the development of wind, solar and low-carbon fuels, plus incentives that will likely catalyze new clean energy jobs. So, problem solved, right? Not exactly. Setbacks Unfortunately, 2023 offered some gut punches to U.S. decarbonization efforts, headlined by setbacks in the U.S. offshore wind industry. In November, European developer Orsted scrapped blueprints for two large offshore wind projects called Ocean Wind 1 and 2 in New Jersey, taking billions of dollars in write-downs rather than tough out the lumps it was enduring in the Garden State. The news drew widespread attention, much of it negative. The Washington Post wrote that the demise of Ocean Wind could “imperil Biden’s energy agenda.” Other observers simply wondered, how could this failure happen in a state with such grand offshore wind ambitions? While Orsted blamed supply chain pressures and financing challenges, it seems local NIMBYism also contributed to the knockout; a commissioner for the county housing Ocean Wind reportedly proclaimed a “very happy day” when the company announced it would abandon the projects. Diversified Portfolios Unlike that New Jersey commissioner, I take no joy in the setbacks our country endures in siting, permitting and executing renewable energy projects. I would, however, encourage states like New Jersey to prepare for similar challenges by adopting a more inclusive energy transition approach: wind, solar and electrification leading the way, but with support from underutilized forms of renewable energy that can bridge the gap in the near- and medium-term. Renewable natural gas (RNG) represents one such technology. Known as biomethane internationally, this low-carbon fuel derived from organic waste has earned tremendous support in Europe, 6 BIOMASS MAGAZINE | ISSUE 1, 2024

where lawmakers are targeting twelvefold supply growth by 2030. But here in North America, RNG remains sorely underutilized. RNG Coalition has identified 43,000 waste sites that could be fitted with methane-trapping RNG infrastructure in the coming decades. Currently, however, North America has just over 300 operational RNG facilities at farms, landfills and other sites, a sharp increase from historic levels, but still far behind our ultimate potential. Considering that methane emissions are 80 times more potent than carbon dioxide over a 20-year span, we have our work cut out for us. It is high time we recognize that our near future cannot be wind and solar alone, as even those widely supported projects are likely to face local resistance and operational challenges, as evidenced by Ocean Wind. Nor can our future be electrons versus molecules, NIMBYs versus industry, or left versus right. A truly sustainable future will require a diverse portfolio of sustainable solutions. Call to Courage This vision will demand courage at all levels of U.S. government, with the 2024 election year underscoring the urgency of the task before us. At the federal level, it’s vital that Washington responsibly implements numerous clean energy incentives originally passed under the IRA, including investment tax credits for RNG and biogas energy properties. At the state level, we need more programs that restrict fossil fuels and encourage renewable alternatives. Michigan has a proposed clean fuel standard that would make it the first state east of the Mississippi to pass a program like California’s historically successful Low Carbon Fuel Standard. It is imperative that Michigan lawmakers push that proposal across in the upcoming legislative session. Ultimately, placing our country in the “right direction” on climate policy means moving decisively to remove ourselves from the yoke of endless fossil fuel dependency. At the same time, we cannot rest our hopes on just a few chosen technologies as we pursue ambitious but hard-to-achieve goals. Viable energy transition policies must confront and navigate this central tension, without expectation of pleasing all parties. Let us hope our federal and state lawmakers embrace this common-sense vision of the energy transition in 2024. And may the new year grant all of us the resolve to march forward in the face of those who would be happy to burden the most important challenge of our era on the backs of a few, select solutions. Author: Dylan Chase Public Relations Manager, RNG Coalition dylan@rngcoalition.com

Utilizing an Asset Management Partner BY KATY FALKENBORG

There are two foundational processes that act as key drivers for the success of every power plant: support and development. A trusted asset management (AM) partner is pivotal to these crucial preparatory elements in each stage of power plant management. The right AM serves as a cross-functional team member with the aptitude for assessing financial goals and objectives, identifying the intricacies of negotiation processes, understanding engineering operations and guiding fuel management, to ultimately ensuring a holistic approach is taken to each unique project. The pivotal roles undertaken by an AM partner in the support and development process of a power plant project are paramount. This strategic alliance plays a critical role in ensuring the seamless functioning and sustained growth of the project. The AM partner assumes the responsibility of overseeing various aspects including project support and development, and in turn, contributes invaluable expertise to ensure optimal efficiency and performance. Through proactive management, meticulous planning and a deep understanding of the intricacies of power plant operations, the AM partner becomes an indispensable force in driving success. The following are the key roles of an AM partner in the power plant project support and development process. Identifying and Executing Strategic Objectives As direct representatives of the power plant, AMs are just as committed to the overarching goals of the facility as the owner. Playing a large role in the oversight of various operations, they have a bird’s-eye view of all that is taking place both in and out of the plant. Because of this, they become a guiding pillar in nurturing stakeholder relationships, leading the enterprise toward its overarching goals by developing strategic values, breaking down silos and encouraging a consistent and clear flow of communication. AMs utilize their experience and relationships to dive deep into the ins and outs of operational dynamics, allowing them to significantly contribute to the enhancement of the organization. Proficiency in Regulatory Compliance Local and government regulations are constantly in a state of ebb and flow. AM teams are charged with staying abreast of the fluctuations to ensure power plants remain ahead of the curve and in full compliance. This allows them to address any shifts and navigate challenges in advance, which is particularly helpful in the dynamically changing environment of renewable energy. For example, AMs can help owners and operators negotiate with wood waste organizations to maintain competitive pricing, even when policies affect facilities. This shows how important the relationship between AM expertise and effective policy engagement is within the power generation industry.

Financial Prowess Asset management and the financial well-being of projects go hand in hand, as there is always a primary focus on revenue targets and expense optimization. AMs have expertise in budget management, contractual commitments and operational challenges, making them a strong asset as plant supporters. Their role entails scrutinizing expenditures, analyzing revenue streams and developing financial plans to keep apprised of the plant’s fiscal health and project trajectory. Such financial prowess serves as a major value-add when it comes to strategic planning and budget efficiency. Achieving Operational Excellence Partnering with an outsourced AM allows power plant owners the opportunity to feel secure with a ready-made solution that is seamlessly integrated into the facility’s overarching business operations. This strategic decision helps streamline operations while providing connections to individuals who have a wealth of knowledge and experience in the field. By tapping a third-party AM partner, owners can put more time and focus into tasks and projects they may otherwise not have had the time for, as they now have the resources available to relinquish the heavy lifting of managing complex internal teams. Strategic Approach to Selecting the Right AM Selecting an experienced AM is more than simply investing in protecting your power plant’s profitability; it’s a decision to find a partner who will become a trusted extension of your internal team and is in full alignment with your organization’s culture and goals. When there is a harmonious relationship between the two parties, innovation and success are achieved. The world of power generation is a dynamic one, therefore the role of AMs in the field will continue to grow in significance. Their unmatched blend of financial acumen paired with operational knowledge, regulatory finesse and cultural alignment is key to power plant project development and support. By taking advantage of the opportunity to work with an AM, plant owners can ensure optimal facility outcomes while fostering growth and success. Author: Katy Falkenborg General Manager and Senior Director of Renewable Energy Asset Management IHI Power Service Corp. ihipower.com

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Biomass News Roundup

Tokushima Tsuda Biomass Power Plant IMAGE: RENOVA INC.

Japan-based Renova Inc. announced that its 74.8-MW Tokushima Tsuda Biomass Power Plant began operations in mid-December. The facility, located in Tokushima City, Japan, is fueled by wood pellets and palm kernel shells. According to Renova, the facility located in the Port of Tokushima-Komatsushima, one of the largest lumber industrial parks in the country. The Port of Tokushima-Komatsushima used to receive a large amount of foreign timber to meet the rapidly growing domestic demand for housing during the period of high economic growth, but over time, the port has been used less and less. With the start of the plant’s operation, the port is expected to be revitalized through the utilization of port facilities for the arrival and departure of fuel transport vessels, and as a result, the creation of new jobs. The Tokushima Tsuda Biomass Power Plant is one of several developed by Renova. In November, the company announced its 75MW Morinomiyako Biomass Power Plant had begun operations. Additional Renova biomass plants that are currently operational include the 20.5-MW Akita Biomass Power Plant and the 75-MW Kanda Biomass Power Plant. Biomass facilities currently under construction include the 75-MW Ishinomaki Hibarino Biomass Plant, the-75 MW Omaezakikou Biomass Plant, and the 49.9-MW Karatsu Biomass Energy. In December, Azure Inc. announced plans to develop a sustainable aviation fuel (SAF) production facility in Cherryvale, Kansas. Since June 2023, Azure has been progressing a frontend engineering and design study, which is on track for completion in 2024, according to the company. Azure is targeting a final investment decision by early 2025. If approved, the company is targeting to reach first production in 2027. Once fully operational, the facility will produce approximately 135 million gallons per year of renewable fuels, primarily SAF.

8 BIOMASS MAGAZINE | ISSUE 1, 2024

Taiwan is considering the use of wood pellets to help boost its use of renewable energy, according to a report filed with the USDA Foreign Agricultural Service’s Global Agricultural Information Network. The opportunity could translate into a $300 million opportunity for wood pellet producers. The GAIN report, filed in November, indicates Taiwan aims to expand its use of renewable energy by 20% by 2025 and reach net-zero emissions by 2050. Currently, renewables account for less than 10% of total energy output in the country. According to the report, Taiwan aims to have 778 megawatts (MW) of biomass energy capacity in place by 2025, enabling 4.1 billion kilowatt-hours of generation. The state-owned power enterprise Taiwan Power Company (Taipower) in 2022 decided to convert a 500-MW, coal-fired boiler at its Kaohsiung Hsinta Power Plant to wood pellets. The report states this is the first project in Taiwan that aims to convert a decommissioned coal-fired unit to biomass energy. The new wood pellet thermal boiler is set to begin operations in 2025 or 2026. According to Taipower, the converted biomass facility will consume approximately 1.7 million metric tons of industrial grade wood pellets annually. Total domestic production is currently in the range of 300,000 to 400,000 metric tons of nonindustrial wood pellets annually. According to the report, Taipower intends to procure the annual 1.7 million metric tons of wood pellets through open tender, with a contract duration of 10 years. The tender is expected to be published during the first quarter of 2024. More than 1.99 billion renewable identification numbers (RINs) were generated under the Renewable Fuel Standard in November, up from 1.95 billion generated during the same period of last year, according to data released by the U.S. EPA on Dec. 21. Total RIN generation for the first 11 months of 2023 reached 21.55 billion, up from 19.39 billion generated during the same period of 2022. Total D3 RIN generation for the first 11 months of the year reached 636.81 million. That volume includes 557.9 million generated for compressed RNG by domestic producers, 42.3 million generated for liquefied RNG by domestic producers, 30.74 million generated for liquefied RNG by importers, 4.92 million generated for compressed RNG by importers, and 947,033 generated for cellulosic ethanol by domestic producers. Total D4 RIN generation for the first 11 months of the year reached 7.12 billion. That volume includes 3.5 billion generated for nonester renewable diesel by domestic producers, 2.3 billion generated for biodiesel by domestic producers, 656.49 million generated for biodiesel by importers, 631.56 million generated for nonester renewable diesel by foreign entities, 19.31 million generated for renewable jet fuel by domestic producers, 15.97 million generated for renewable jet fuel by foreign entities, and 656,460 generated for renewable heating oil by domestic producers.

BIOMASS NEWS ROUNDUP¦

Total D5 RIN generation for the first 11 months of 2023 reached 239.85 million. That volume includes 112.11 million generated for nonester renewable diesel by domestic producers, 69.71 million generated for naphtha by domestic producers, 27.28 million generated for ethanol by domestic producers, 21.24 million generated for ethanol by importers, 4.36 million generated for liquefied petroleum gas by domestic producers, 3.71 million generated for renewable heating oil by domestic producers, and 1.44 million generated for compressed RNG by domestic producers. Total D6 generation for the first 11 months of this year reached 13.56 billion. That volume includes 13.4 billion generated for ethanol by domestic producers, 101.13 million generated for nonester renewable diesel by foreign entities, 34.72 million generated for renewable gasoline by domestic producers, 11.28 million generated for ethanol by importers, 4.15 million generated for biodiesel by domestic producers, 3.22 million generated for biodiesel by importers, 3.08 million generated for renewable jet fuel by domestic producers, and 941,847 generated for nonester renewable diesel by domestic producers. Total D7 RIN generation for the first 11 months of 2023 reached 208,643, all of which were generated for cellulosic heating oil by importers. The government of British Columbia on Dec. 11 released regulations for its revamped low carbon fuel standard, becoming the first jurisdiction in North America to require the use of sustainable aviation fuels (SAF). Among the changes to the BC-LCFS is a new requirement that fuel suppliers incorporate low carbon jet fuel into fossil jet fuel. The regulations require renewable fuel to comprise at least 1% of jet fuel starting in 2028, increasing to

2% in 2029 and 3% in 2030 and subsequent compliance periods. The regulations also include a carbon intensity reduction requirement for jet fuel that phases in at 2% in 2026, 4% in 2027, 6% in 2028, 8% in 2029 and 10% in 2030 and subsequent compliance periods. Peak Renewables in early December announced it has secured the sale of existing equipment at a former Canfor manufacturing facility in Fort Nelson, British Columbia, and that the company is working to redevelop into a wood pellet plant. According to Peak Renewables, the sale of existing equipment at the former Canfor PolarBoard manufacturing plant will kick-start activity at the site over the upcoming months. “The equipment removal marks a pivotal milestone in our aspirations to reopen the facility as a pellet-producing plant as [the removal] makes space for pellet manufacturing equipment,” the company said in a statement. Peak Renewables has been working to redevelop the site into a 600,000-metric-ton-per-year wood pellet plant for several years. In 2020, the company reached an agreement with Canfor to purchase the Fort Nelson mill assets. Also in 2020, Canfor announced it had reached a multiyear agreement with Peak Renewables involving the sale of the company’s forest tenure in the Fort Nelson region. The government of British Columbia in August 2021 approved the transfer of the forest tenure. An update issued by Peak Renewables earlier this month explains that the biggest issue in moving forward with the pellet project is the viability of the railroad. The company indicated CN Rail is working aggressively on the challenge to find a timely, cost-effective solution.

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¦SPOTLIGHT Mid-South Engineering

Leading Clients to the Finish Line In 2023, Mid-South Engineering served an impressive 120-plus clients, executing over 250 projects in a variety of industries, with a focus on biomass and wood. The company shared some of the year’s highlights with Biomass Magazine, as well as emerging sectors and perspective on the value of engaging an experienced firm. Q: 2023 just came to a close. What were some highlights of the year? Are there any trends or industry hot spots you anticipate in 2024? Mid-South: Pellet project development continues to be a dynamic space. Demand for pellets is strong, and we believe the industry will grow over the long-term as energy demands increase. Our team has been actively engaged with clients in optimizing pellet production processes and increasing efficiency. Some other things we see from clients are a commitment to clean air initiatives and upgrades to more efficient machinery, and more focus on improving and expanding the drying side of the process. For trends and hotspots, we’ve conducted numerous feasibility studies for clients re-

lating to the viability of projects ranging from biochar to torrefied pellets, to graphene using feedstocks from woody biomass to bagasse to municipal waste. Over the past three years, we have worked on several biochar projects and various projects related to renewable diesel and biodiesel. Another biomass feedstock segment of our portfolio includes combined heat and power (CHP). If a client wants to construct a CHP biomass plant, Mid-South can model a facility’s energy needs to balance the available raw materials with the necessary equipment, allowing them to make informed, data-driven decisions on capital spending. Q: Mid-South has been around for 55-plus years, armed with a vast amount of experience and knowledge. How does that translate into value for clients? Mid-South: With a history spanning more than five decades, we bring a wealth of project experience to the table. Our seasoned professionals prioritize guiding and mentoring our younger engineers. We’re committed to teaching the next generation of engineers and sharing our knowledge with clients to help aid successful projects, leveraging our deep under-

standing of biomass and plant design. Clients are facing the workforce challenges we hear about in the news, and in turn, rely more on industry leaders like Mid-South to get projects to the finish line. Our internal mentoring, collaboration and knowledge sharing is influential in helping clients deliver projects. Ultimately, our value comes from more than lines on construction drawings—it comes from our experience and knowledge of what is actually needed for a successful project and what that path looks like. We assist clients with aspects of a project beyond design engineering as they see gaps in project control activities such as project schedules, management and budgeting, and on-site support. In the end, engineering represents less than 5% of a project’s total cost, but a key point is this small percentage and the experience we bring can affect the large capital costs where real savings can be achieved, especially when things are properly considered on the front end. We pride ourselves in being collaborative partners and focusing on efficiently utilizing our client’s resources.

¦SPOTLIGHT Pick Heaters Inc.

Choosing Pick Steam Injection Having developed and patented a unique direct steam injection (DSI) system in 1945, Pick Heaters has more than 15,000 installations in the food, chemical, pulp and paper, power, oil and gas, biomass and other industries, remaining an industry leader by continuously refining and innovating its DSI products. Pick offers a range of DSI heater models, the fit depending on application needs. For example, a Pick BX Steam Injection Heater offers precise heating of starch and water-miscible slurries. “It’s a great choice for viscous slurries like wastewater heating, waste grease, fats, oils and grease (FOG) sludge or oil extraction,” explains Mark Brueggemann, vice president of Pick. “We will fabricate steam injection heaters for special materials of construction or for pipe size outside the norm—we have the engineering and manufacturing skills to meet a customer’s exact requirements and specifications.” As for how they work, DSI heaters can be used wherever medium- to high-pressure steam is available and an unlimited supply of industrial hot water is needed, or to heat liquids or slurries in-line. “The Pick System injects steam into the

liquid through hundreds of small orifices across a steam injection tube,” Brueggemann explains. “A fine mist of steam is instantly absorbed by the liquid, resulting in 100% heat transfer with all steam condensed withing the heater body. A unique spring-loaded piston rises or falls as more or less steam is required. This prevents pressure equalization between steam and water pressure, thus eliminating steam hammer. Helical flights in the chamber promote thorough mixing prior to discharge.” Advantages include, but are not limited to: energy efficiency (savings of up to 28% in fuel costs), exceptional temperature control (plus or minus one degree Celsius), a wide operating range, no steam hammer, low noise, compact design and low maintenance costs. As for what differentiates Pick from competitor systems, Brueggemann points to the steam mixing chamber and internal injection tube of the Pick System as being the key performance features. “The injection tube smoothly injects steam into the process flow,” he says. “It eliminates shock, hammer, noise and vibration. The heater body is designed around low veloci-

ty mixing action, providing negligible liquid side pressure drop, low sound level and no downstream piping requirements for condensing of steam.” On the most active sectors in the biomass industry, Brueggemann says it has been in animal waste—manure-to-fuel operations. “Introducing heat to the process enhances the breakdown and conversion for the production of biogas,” he explains. “Equally prevalent has been separation of FOG in waste treatment. Adding heat to this process maximizes the separation of these byproducts, resulting in not only savings in waste treatment costs but also providing a valuable source of added revenue.” Brueggemann emphasizes the company’s goal of providing systems that are engineered to each unique application. “Off-the-shelf equipment only works if the customer’s process fits with the supplier’s model,” he adds. “With industrial equipment, it’s not like selling shoes. At Pick, we gather all the facts, the application conditions to select and size the equipment, as well as an understanding of the complete process.”

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¦PROFILE

The Keyes to

Success

With operations in ethanol, biogas and RNG, sustainable aviation fuel, biodiesel and more, Aemetis’ endeavors have a common denominator: waste utilization and low carbon intensity. BY KEITH LORIA

n February of each year, Aemetis releases its updated five-year plan to share insights into the company’s vision and revenue strategies, highlight milestones reached and expound on new goals. While its 2024 version has yet to be released, Chairman and CEO Eric McAfee—the man leading the charge since the beginning—believes in a bright future for the company. McAfee’s roots in biofuels extend back two decades, to when he founded Pacific 12 BIOMASS MAGAZINE | ISSUE 1, 2024

Ethanol in 2003. For that operation, which was focused on corn ethanol, he raised $85 million from Bill Gates’ investment fund, and then another $146 million at a billion-dollar valuation of public stock offering after the company went public. Pacific Ethanol became worth about $1.8 billion by 2006, but McAfee was just getting started on building out a low-carbon, waste utilization empire, and that same year founded Aemetis.

A Versatile Portfolio

“I wanted to do waste, low carbon intensity, low cost—all the benefits of waste feedstock,” McAfee says. Soon after Aemetis was formed, its subsidiary, Universal Biofuels, began construction of a 50 MMgy biodiesel and refined glycerin plant in Kakinada on the east coast of India. Construction was completed in 2010, an upgrade to process lower-cost feedstocks was done in 2019, and an expansion to 60 MMgy was completed this past September. Plans are to

expand even further, to 80 MMgy by midnext year, and 100 MMgy by 2025. Currently, it is the largest biodiesel plant in India. In 2012, two years before Aemetis stock began trading on NASDAQ, the company acquired and upgraded a 65 MMgy ethanol production facility in Keyes, California. “Fundamentally, we are just optimizing a single corn ethanol plant and showing that this is how beneficial a single plant can be,” McAfee says. “When you produce distillers’ grain, you’re feeding cows, which

leads to waste. That manure is the world’s lowest-carbon-intensity source of biogas. So, an ethanol plant actually indirectly produces biogas waste. We ended up launching a $400 million biogas business [beginning in 2018] and we also supply these dairies with animal feed.” The Aemetis ethanol facility supplies about two million pounds per day of animal feed to more than 80 dairies, feeding more than 100,000 dairy cows in the local area.

In 2022 came the Aemetis Carbon Capture and Sequestration Project at Riverbank, which was the first to ever receive a CO2 sequestration characterization well permit issued by the state of California. The goal at the 24-acre site, known as “Parcel B,” is to serve as the key site for 1 million annual metric tons of planned CO2 injection to reduce the carbon intensity of Aemetis biofuels, and sequester CO2 from other California industrial and agricultural sources BIOMASSMAGAZINE.COM 13

¦PROFILE

Within its first dozen years of operation, Aemetis has reduced 12.9 million metric tons of CO2 from the low-carbon ethanol produced versus gasoline that would have been consumed, and has also been responsible for more than 8 billion pounds of animal feed (wet distillers grains) and over 100 million pounds of distillers corn oil for biodiesel production. “It’s all just a logical extension of what you put into an ethanol plant, and what you get out of an ethanol plant; if you can reduce the inputs and reduce the carbon intensity going in, then the product coming out is higher value, and that’s what we’re really focused on,” McAfee says. The ethanol plant recently completed a $12 million upgrade, which included a changeout of all controls to an Allen Bradley system with artificial intelligence, energy management and operational capability, as well as the addition of a solar system with battery backup. The project received an $8 million grant from the state of California. Aemetis Biogas is building anaerobic digesters at California dairies to capture biomethane from animal waste. After removal of contaminants and pressurization of gas at the dairy, a biogas pipeline connects the dairies to a centralized facility lo-

‘Fundamentally, we are just optimizing a single corn ethanol plant and showing that this is how beneficial a single plant can be.’ —Eric McAfee, Aemetis Inc. Eric McAfee, Aemetis Inc.

cated at the Aemetis Keyes ethanol plant, where the biogas is upgraded into negative-carbon- intensity RNG. The RNG is injected into the Pacific Gas and Electric gas pipeline, an interconnection that was opened in June 2022, along with Aemetis’s RNG cleanup and compression unit. To date, the RNG project has signed 37 dairies to supply biogas digesters with animal waste. Seven have been completed and are operating, with 10 more under construction. Aemetis has also installed over 33 miles of biogas pipeline that will be utilized for the next 30 digesters, having been approved for another 21 dairies and 24 miles of pipeline. Aemetis closed on its second

$25 million USDA loan guarantee this past summer to support construction of additional digesters, and the company expects a third $25 million loan to close in the near future. In 2022, Aemetis acquired the Riverbank Industrial Complex, a 125-acre U.S. Army base with 710 square feet of buildings, which was once used to make army ammunition. Of that, 50 acres is permitted for construction. The company received its Use Permit from the city of Riverbank and approval from the California Environmental Quality Act in September, and an air permit is in process for approval, expected in the first quarter of 2024. “Since we have

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The Aemetis Biogas pipeline project, including the dairy digesters, collection pipeline, centralized biogas upgrading facility, RNG fueling station, and PG&E gas pipeline interconnection, is investing more than $300 million in the region. Approximately 36 miles of pipeline has been built to date, with seven operating digesters and 10 more under construction. IMAGE:AEMETIS INC.

BIOMASSMAGAZINE.COM 15

The Aemetis Keyes Ethanol Plant also produces animal feed for 100,000 local dairy cows at 80 local diaries, CO2 for the food and beverage industry through a partnership with Messer Gas, and distillers corn oil for poultry feed. IMAGE:AEMETIS INC.

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PROFILE¦

that [Use Permit], we can complete project financing and start building a 90-million-gallon renewable diesel and sustainable fuel plant,” McAfee said. “We’ve signed $3.8 billion of contracts with 10 airlines—a billion with Delta [Air Lines] and a billion with American [Airlines], and also have a $3 billion contract with a travel stop company.” Over the next few months, Aemetis plans to complete the installation of a $10 million solar microgrid with battery backup adjacent to the Keyes plant. The solar array will generate approximately 3.2 million kilowatts per year and reduce greenhouse gas emissions by around 8,000 metric tons of CO2e per year. “The microgrid creates energy resiliency and will assist with off-peak load shedding and energy efficiency,” McAfee explains. “This microgrid, along with other energy saving technologies being implemented at our low-carbon ethanol facility, will further reduce the carbon intensity score of the fuel ethanol produced.”

Finally, the company has received permits, completed engineering, fabricated equipment, and is now installing an RNG fueling station at the Keyes ethanol plant to fuel trucks, and expects the station to be operational in January. “We also have a mechanical vapor recompression project that’s a year away from being completed, but it will be one of the world’s only implementations at an ethanol plant,” McAfee says. “This system turns your ethanol plant into an electric-powered facility. We’re going to be removing more than 90% of the natural gas use in our plant—that’s petroleum energy and the electricity source—and replacing with grid electricity. Our grid happens to be largely hydroelectric power or solar. It’s very low carbon intensity and relatively low cost.”

Political, Support Challenges

To date, Aemetis has sold $63 million in tax credits and received $55 million in cash as one of just a few Inflation Reduction Act

tax credit sales that have been transacted. “The Aemetis Five Year Plan is expected to qualify for more than $800 million of IRA investment and production tax credits during the next four years to support our biogas projects, CO2 reuse by our ethanol plant, the construction of our sustainable aviation fuel plant and CO2 sequestration,” McAfee says. “We are bullish on the Inflation Reduction Act, we think that we know how to transact with buyers and all the different advisors, and now it’s just a matter of execution.” He adds that the political landscape with a presidential election coming up has caused some concern among investors about whether the Inflation Reduction Act is going to be substantially changed, but believes CCS carbon sequestration is probably going to be a favorite regardless of which party is in the White House. While many biofuel companies have come and gone through the years, Aemetis has been successful, McAfee notes, because

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¦PROFILE

of the long-term view it takes. “Not all companies have the appetite for the kind of external, regulatory and Wall Street market volatility,” he says. “In our particular case, starting roughly 10 years ago, the U.S. government decided not to enforce federal law, and so for 10 years, a core risk in our industry has been whether the Renewable Fuel Standard would be enforced by the [U.S.] Environmental Protection Agency, and the answer in every single year since 2013, until June of this year, was no.” Therefore, it’s an industry in which certain enterprises have been very successful at scaring the White House, so investments in the industry have been damaged, he adds. “The lenders have a lack of confidence in regulators actually enforcing federal law,” McAfee said. “It’s very difficult to do 20year financings when the fundamental risk is decisions by regulators that violate federal law. It’s an amazing truth about our entire industry, and an unfortunate truth.”

McAfee also feels there is a need for the EPA to clarify that electric car renewable identification numbers, or eRINs, are not going to be designed to destroy the markets for liquid fuels. “The EPA has done some foolish decision making in the past, starting with their active violation of federal law—numbers that are set out that say you will mandate this amount, signed by Congress, signed by the president,” he said. “When they have no accountability for that, you have a substantial risk of further wrongdoing by the EPA. And it’s too bad.”

Looking Ahead

Every February, Aemetis posts its five-year plan, which includes its financial projections and cash flow, debt and capitalization and everything else that pertains to the company and where it’s going. The most recent version unveils plans to target $2 billion of revenue in 2027.

The future looks strong, according to McAfee. “We expect to continue to move forward with what we believe to be the original intent of the federal Renewable Fuel Standard and the California Low Carbon Fuel Standard,” he says. “The Scope 3 emissions are something that sustainable aviation fuel has a really great promise to be able to help. These are pro-environment, pro-jobs, pro-investment, pro-clean air, kind of policies that simply lack consistent commitment by policymakers. The next step in this journey is whether California and Gov. Newsom are actually committed to investment in jobs and cleaner air, and lower-carbon emissions.”

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¦BIOCHAR

RESTORE AND

e v i v e R

Located across the road from a pellet plant, a new biochar facility is under construction in Virginia—the carbon credits of which have been purchased by Microsoft. BY KATIE SCHROEDER

n a world under pressure to reduce carbon emissions and improve the environment, biochar is a proven means of storing CO2 and restoring soil quality. In a mission to bring biochar to the southeastern U.S. and give local farmers a way to improve soil while sequestering carbon, Restoration Bioproducts is building its flagship facility in Waverly, Virginia. With intentions for the plant to serve as proof of concept for its model of building small biochar plants in rural areas, the company is embracing a risk-averse approach to growing the biochar industry. 20 BIOMASS MAGAZINE | ISSUE 1, 2024

The Waverly Project is the culmination of decades of experience in the biomass industry, explains Jeff Waldon, managing partner of Restoration Bioproducts. He and the other partners bring a variety of biomass related experience to the table. Waldon is a researcher with background at Virginia Tech, including in biomass and biomass energy, and he serves as the treasurer for the U.S. Biochar Initiative. Other partners include Langseth Engineering, an engineering firm based out of Lynchburg, Virginia, that is involved in growing biomass energy and pellets, and FDC Enterprises, an ag services

company that assists landowners in converting their land to seeds and grasses under the Conservation Reserve Program, as well as growing bioenergy crops. “When we first started Restoration Bioproducts, we had all worked in rural communities, and we were all very intently focused on how this could impact small towns and places like Waverly,” Waldon says, adding that their strategy focuses on building “appropriately sized” facilities for each local community and the feedstock available.

Location and Product

Located on land leased from pellet manufacturing plant Wood Fuel Developers, the facility will have easy access to the pellet plant’s waste stream of wood flour and wood nibs as a biochar feedstock. Because the facility is situated just across the road, the close proximity between the entities reduces costs and the carbon intensity of the final product. The pellet plant will not be the only feedstock provider, Waldon explains, as his team is developing contracts with other suppliers as well. Most of their other feedstock supply will be pine re-

siduals—almost exclusively loblolly pine— from local wood mills, either conventional lumber mills or pellet plants. Eventually, they may also buy hog fuel from local timber harvest operations as well. The Waverly Project will use two and a half tons of feedstock each hour; however, later projects are planned to scale up to about five tons per hour. “The first one is proof of concept—it was intentionally smaller than the one we’re going to do ultimately,” he says. “The five-ton-per-hour system, I think [it] hits the sweet spot of available feedstock and project side.” The

smaller-scale Waverly facility is planned to produce 8,300 tons of biochar per year. The biomass is put through pyrolysis, the process of heating fuel in the absence of oxygen, and is heated to 400 degrees Celsius (752 degrees Fahrenheit), creating biochar and forcing off volatile compounds to create a syngas. “That gas is then harvested out of the machine and pumped back through a burner because it’s got a fairly high Btu content,” Waldon says. “And that burner is what heats the pyrolysis kiln. It’s … autothermic, [meaning] it self-heats.” Since a fuel source is needed to start the auBIOMASSMAGAZINE.COM 21

Cashing in on Credits In September, Carbon Streaming Corp. announced that it will provide Microsoft with carbon removal credits from the Waverly Biochar project, which is expected to deliver up to 10,000 metric tons of carbon dioxide removal credits per year toward Microsoft’s carbon negative target. As for how this model works, Carbon Streaming describes its approach as providing “project capital to project developers, enabling them to accelerate their projects. This also provides a major benefit to corporations using carbon credits as part of their climate strategies. Rather than having to provide upfront capital to climate projects, corporations can instead commit to purchasing the verified removal upon issuance.”

22 BIOMASS MAGAZINE | ISSUE 1, 2024

This three-way relationship among Carbon Streaming, the project developer and corporate end users, according to the company, aims to remove upfront investment barriers to corporate action. Carbon Streaming’s current portfolio includes another biochar project in Enfield, Maine, being developed by Standard Biocarbon Corp. The project employs carbonization systems engineered and built by German company PYREG GmbH. Carbon Streaming has a royalty on the 250,000 cubic yards of biochar that is expected to be produced and sold by the project over its 30-year life, according to the company.

BIOCHAR¦

though some studies show much longer times of 1,000 years—helping increase the soil’s organic carbon accretion. “If we take our biochar and we put it on a farm field, that’s carbon that we’ve literally taken out of the air using plants as intermediates, put it in the soil, and it stays there for at least a hundred years. Depending on whose model you look at, it’s a thousand years,” he says. Project construction began in April 2022 and is slated for completion in the first quarter of 2024, with biochar production beginning in Q2 2024. IMAGE: RESTORATION BIOPRODUCTS

tothermic process, the Waverly Project will use biodiesel to get it up to temperature. The surplus syngas is piped into a condenser and turned into pyrolysis oil, which can be used as a precursor to many different fuels, including sustainable aviation fuel, biodiesel or heating oil. In future projects, Restoration Bioproducts intends to fractionate

the pyrolysis oil into a variety of products, such as wood vinegar, made up of the acetic acid derived from the pyrolysis oil, which can be used for a variety of applications. The biochar itself will be trucked to farmers, with the help of FDC Enterprises. Biochar is 85 to 95% carbon and can contain it in the soil for a least a century—

Carbon Credits

The sequestered carbon in the soil is a vital part of the value structure of the facility, as Microsoft has bought the rights to the Waverly Project’s carbon dioxide removal credits from the biochar. Waldon explains that the carbon credit market is currently only voluntary, but many large companies like Microsoft have made commitments to become carbon neutral by a certain date and are opting for carbon reduction strategies that achieve direct re-

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¦BIOCHAR

moval of carbon dioxide, rather than offsetting emissions. “There’s a tremendous amount of interest in this nascent industry,” Waldon says. “There are all kinds of things going on behind the scenes—there’s a dozen different stealth activities going on. Stay tuned, the announcements I think are going to come fast and furious [in 2024].” A lifecycle analysis is needed to determine how many carbon credits are awarded per dry metric ton of biochar. Waldon

explains that transportation emissions are a major determining factor in calculating the value of credits, as the distance the feedstock travels to the plant and the distance biochar travels to reach the field are both taken into account. “Our [transportation emissions] are going to be fairly pedestrian, I think,” he says. “We’re kind of in the middle. Some of the ones out west are going to have a really long-haul rates for their feedstock. Some of the ones in the Midwest

'5<(56 72 *(7 ,7 '21( ,7 '21( Equipment at the Waverly Project will annually process 28,000 green tons of waste wood fibers into biochar, wood vinegar, bio-oil and power, according to Restoration Biopoducts. IMAGE: RESTORATION BIOPRODUCTS

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are going to have a bigger, they’re going to have much shorter haul rates to the fields or wherever they’re taking their product, even though the front-end cost of their feedstock’s going to be higher.” The company’s strategy is focused on constructing many modest-sized plants rather than a single large facility. Waldon explains that though the return on investment may not be as high using this strategy, the risk management benefits are worth it. “I’m optimistic that we can do a whole bunch of these projects in a lot of different places,” he says. The project started construction in April 2022 and is slated for completion in the first quarter of 2024, with production beginning in the second quarter of 2024. The initial 12-month timeline of the project has stretched out to 19 months due to supply chain delays. “We got everything squared away, got the money required, ev-

erything is ordered, just need[ed] to be delivered,” Waldon says. “But it took a lot longer than anybody expected it to, and time is literally money in these kinds of projects.” In the future, Waldon plans to budget for 18 months for projects to account for any unexpected vendor delays. Restoration Bioproducts has several projects planned for the future, including a project located in Iowa that would use switchgrass as its feedstock, Waldon says. Switchgrass is a more expensive feedstock because it is a purpose-grown energy crop, but the biochar will have a greater number of farmers close by. Other projects are in development across the nation, ranging from Texas to the Appalachians to the West Coast, according to Waldon. “We’ve got one other project we expect to announce here shortly, but it won’t be up and running until probably the first quarter of 2025,” he says. “And after that I don’t know, I’ve got a half dozen projects literally ready to go, and we’re shopping them to investors right now.”

The Waverly facility will employ five people per shift, with the total number varying somewhat depending on how many shifts there are. Most of the positions need only basic equipment operating experience, making them accessible for members of the community. This facility is not able to solve the local economy’s problems, but Waldon explains that it is a “step in the right direction. We’re in a position where we can actually pay pretty well, even for [less skilled]

positions, and that’s an intentional choice on our part,” Waldon says. “[I’ve] hired enough people over the years to know that paying at the bottom of the scales doesn’t save you any money. You’re in a competition for the best people, and you need to internalize that fact. So, if I have to pay more to get the best people, it’s totally worth it.” Author: Katie Schroeder Katie.schroeder@bbiinternational.com

Futureproofing, Economic Impact

Another risk reduction strategy Restoration Bioproducts exercises is having multiple product lines and feedstock options, allowing them to adapt as needed. Waldon sees a future in pyrolysis oil as a potential feedstock for SAF, once the supply chain and intermediate technologies are developed. “[You’ve] got to have every part of the system working together,” he says. “It’s just like anything else in biomass, if you don’t have the offtakes and application ready, then you can’t really justify the investment in the front end—it’s all pieces and parts that have to track one another.” Restoration Bioproducts’ approach to project development prioritizes employing people in rural communities, where good paying jobs may be difficult to find. Waverly is a small town, with a population of 1,875 people. Waldon explains that the economy in the area was negatively impacted by the closing of a Masonite mine that employed many people in the area.

MAR. 4-6 2024 BOOTH 420

BIOMASSMAGAZINE.COM 25

Tom Buis, CEO of the American Carbon Alliance, was a keynote speaker at the National Carbon Capture Conference & Expo. IMAGE: TIM PORTZ

THE QUEST TO

CAPTURE CARBON Policy, regulation and project finance were main topics of discussion at the National Carbon Capture Conference & Expo

BY ANNA SIMET

he ethanol industry’s potential to decarbonize through carbon capture and play a substantial role in the buildout of the sustainable aviation fuel industry was one of many focuses at the second annual National Carbon Capture Conference & Expo, held in Des Moines, Iowa, in early November. Keynote speaker Tom Buis kicked off the event by chronicling his journey from a young farmer to a prominent ethanol industry advocate, to now CEO of the American Carbon Alliance. Referring to the Renewable Fuel Standard as the “greatest economic driver of all time for profitability in agriculture,” Buis discussed his time serving as the senior agriculture policy advisor for Senate Majority Leader Tom Daschle, D-South Dakota—who he 26 BIOMASS MAGAZINE | ISSUE 1, 2024

referred to as “the first author of the RFS”—as well as his roles as National Farmers Union president and CEO of ethanol trade group Growth Energy. The ethanol industry is working hard at reducing its carbon footprint, Buis said, which can easily be done through carbon capture. “You put it in a pipeline, which is the most efficient, economic and safest transportation mode … but it has become controversial due to a very few number of critics who are very good at scaring people and promoting misinformation.” Buis said lowering the carbon index of ethanol would have a huge impact on farm income, particularly when it comes to seizing opportunities in the sustainable aviation fuel (SAF) industry. Howev-

CARBON¦ er, the way ethanol’s carbon index has been historically viewed is prohibitive for producers to take advantage. “It has been controversial from the very early days of the Low Carbon Fuel Standard in California, where the modeling charged ethanol with all kinds of things that it should haven’t, indirect land use change ... blaming U.S farmers for tearing down the rainforests in Brazil to produce corn, which isn’t the case and never will be ... it gave us a bad score that has stuck,” he said. “They don’t use updated modeling like the GREET model, for which we’re all advocating.” In order for ethanol producers to participate in the SAF market—particularly to qualify for tax credits provided in the Inflation Reduction Act—the GREET model must be accepted for carbon accounting, Buis said. “In order to qualify for that market, you have to have a carbon index low enough to meet requirements,” he said. “For ethanol [producers], capturing carbon and sequestering it cuts its carbon index in half, which makes us qualify to produce SAF and higher blends in the marketplace ... in low carbon fuel states like California, Washington, Oregon and others. The benefit is tremendous.” Buis pointed to the significance of the SAF Grand Challenge requirement of 3 billion gallons of domestically produced SAF by 2030. “That’s a gigantic market, but it’s only available if we succeed in capturing and sequestering carbon,” he said. “You’ve probably heard a lot of criticisms from people trying to portray pipelines as dangerous—they’re not—or as not necessary. Well, I don’t know how else you transport the carbon from an ethanol plant; it would take all the trucks in the world to haul that stuff, because you have to sequester the carbon to areas that have geological formations.” Though Navigator’s Heartland Greenway CO2 pipeline was cancelled—a project that would have captured up to 15 million metric tons of CO2 annually from 30-plus ethanol plants across five Midwestern states—Buis said Summit Carbon Solutions’ project, which involves 30 ethanol plants, is still moving forward. “It’s going to tie in all ethanol between Illinois and North Dakota, plants located in states that can’t directly pipe that carbon into the ground,” he said. “What that means is economic opportunity. It means profitability for farmers, it means new demand, it means profitability for ethanol companies. One of the reasons I’ve always been an advocate for rural America is the rural communities. You can’t sustain a rural town if you don’t have the infrastructure for people to live there … that doesn’t happen if they don’t have economic opportunity. If you don’t believe me, drive to the location of an ethanol plant, and you’ll find a vibrant economy.” Buis ended by encouraging attendees to get involved and reach out to legislators. “This is all about getting on board,” he said. “This is our opportunity, and we can’t miss it. What can you do? ... You can be contacting policymakers. Contact local elected county supervisors. Contact the media and tell them how important this industry is. Lowering our carbon intensity is our survival.”

Tragedy of the Commons

Following Buis’ remarks, SCS Technologies’ CEO Cody Johnson took the stage, beginning his discussion by emphasizing that Texas has been safely operating pipelines for the better part of a century, and the benefits those pipelines have on surrounding communities. “We’ve been living with [pipelines] since the 1960s, starting with cap-

turing carbon and reinjecting the CO2 into our geology for enhanced oil recovery,” he said. “It’s a world of difference in communities that have it and those that don’t.” Johnson segued into discussing the critical point that society has reached in terms of needing to execute actions to reduce CO2 emissions and mitigate climate change, and the tradeoffs between global population growth and energy poverty, security, density and reliability. “So often, we focus on project economics and policy, and it’s more than just that,” he said. “Our generation and those before us have waited so long to make tough choices that now, our options are limited. By acknowledging the complexity of the social and political choices we must make—and being realistic about what our choices are and how much time we have left to act—we put ourselves at a better chance to succeed.” Johnson called the situation a “tragedy of the commons, an economic situation where individuals consume resources at the expense of broader society. If individuals continue to act in their self-interest, it can result in harmful overconsumption to the detriment of all, and it may result in underinvestment and total depletion of resources for future generations” he said. Giving the example of traffic congestion, littering, overfishing and air pollution, Johnson said this is what society has been doing for the past three generations. “We’ve been consuming goods, fuel and materials using processes and practices that create and release CO2 into our atmosphere, unabated, and without recognizing any cost of production passed onto the consumer.” Because there is no direct cost to the production of CO2 emissions, Johnson said there is no incentive to stop. “Now that we’re near the max amount of CO2 we can safely pack into our atmosphere, we all realize we need to do something about it. But nobody wants to pay for it, nobody wants to curb their appetite, and nobody wants a pipeline in their back yard.” Despite policy efforts from local to global levels, Johnson said he believes that goals cannot be achieved without carbon capture utilization and storage. Touching on energy security, he remarked that solar and wind can’t fight offensive or defensive wars. “You need energy-dense ethanol, sustainable aviation fuel or hydrocarbons,” he said, underscoring the price volatility, supply and security issues the Russia and Ukraine war has had on global energy markets. “How do we balance the right of energy access, the necessity of energy security and practicalities of energy density and reliability, all while mitigating the worst impacts of climate change?” Johnson added. “CCUS. Capturing CO2 emissions from the source or directly from the air ... to utilize them in products or processes ... or store them under ground.”

Policy and Projects

Following Johnson, Joey Minervini, senior consultant at the Global CCS institute, provided an update on the latest developments in carbon capture and storage project development and policy, beginning with the rationale as to why CO2 emissions need to be addressed, particularly the fact that 2023 set some alarming temperature records. “The global scientific community has reached a consensus that to avert the worst effects of climate change, we need to get to net zero emissions,” he said. The Intergovernmental Panel on CliBIOMASSMAGAZINE.COM 27

Cody Johnson, CEO of SCS Technologies, called carbon capture the “lynchpin to solving a global tragedy of the commons.” IMAGE: TIM PORTZ

Joey Minervini, senior consultant at the Global CCS Institute, discussed domestic and global projects and policy in carbon capture and storage. IMAGE: TIM PORTZ

mate Change has studied all viable pathways to achieve net zero, Minervini said, and three out of four pathways presented all require CCS. “The IEA (International Energy Agency) has arrived at the same conclusion.” CCS is a proven technology that has been safely and effectively implemented in the U.S. for 50 years, but progress has not been linear, Minervini said. That’s for a few reasons, one of which is how the portfolio of projects has evolved. “The first wave of projects was driven by an influx of funding after the global financial crisis in 2008,” he said. “The Recovery Act provided $3.4 billion for CCUS through the U.S. DOE at the time. Unfortunately, after all that stimulus started to dry up, projects started to get pulled down domestically and across the globe. Since then, we’ve seen a reversal of the trend, steady growth since about 2017, and some of that can be attributed to policy actions.” One significant policy action was the 2015 the Paris Agreement, according to Minervini, and more recently in the U.S., improvements to mechanisms like the 45Q tax credit, which incentivizes CO2 storage. “Another factor driving growth is increasing awareness of the climate problem, and recognition that CCS is part of the solution,” he said. “This isn’t just permeated in the public sphere, but corporate as well, and manifests in things like ESG (environmental, social and 28 BIOMASS MAGAZINE | ISSUE 1, 2024

governance) expectations, sustainability efforts and net-zero commitments.” Other recent drivers include funding in the recent Bipartisan Infrastructure Law and the Inflation Reduction Act. “In a second wave of projects, we’re seeing an increase of CCS hubs or networks—projects in which there are multiple emitters sharing a common transport source,” Minervini said. “Companies are beginning to recognize and leverage the economies of scale associated with sharing these infrastructure and storage resources.” In the past year, 63 new facilities have been added to the project pipeline, and that number is growing, according to Minervini. “Across the globe, there are now 26 countries with commercial CCS facilities either in operation or under development.” North America and Europe are seeing high growth, while the Middle East, China and Asia Pacific regions are seeing some development as well, he said. Like Johnson, Minervini said net zero cannot be achieved without CCS. There are some pros and cons to each technology, he acknowledged. For example, point source capture is very efficient, but it must be built at an industrial site where emissions are being generated. Direct air capture is geographically flexible and a plant can be built nearly anywhere—enabling operators to eliminate or minimize the cost of transport for CO2—but it is also expensive, not as efficient and requires the added cost of using renewable or low-carbon energy to run the project if the project is to be truly carbon neutral. DAC runs on the order of $400 per ton, Minervini said, emphasizing that it is not a substitute for carbon mitigation. “We absolutely need DAC ... but we also need to be mitigating emission by capturing at point source,” he said. As for movement in the U.S., several states beyond Texas and Louisiana—including Colorado and Wyoming—are beginning to recognize opportunities associated with the CCS industry and pass laws to remove administrative barriers, as are corporations that have no other immediate way to reach environmental goals, Minervini

CARBON¦

said. He gave the example of Microsoft and JP Morgan signing purchase agreements for carbon credits earlier this year. “Another sign of the durability of this industry happened earlier this year, when Occidental [Petroleum] purchased Carbon Engineering, a direct air capture company, for $1.1 billion—that’s a signal of their commitment to DAC … their CEO said they intend to build 100 DAC facilities by 2035,” Minervini said. “So, despite challenges, the industry appears to be here to stay and poised to grow.” Minervini provided an overview of regions of the U.S. where CCS is moving rapidly and highlighted specific projects, including the aforementioned Summit Carbon Solutions ethanol plant project in the Midwest, the project type of which he called “extremely complex, particularly when you’re moving CO2 across local jurisdictions,” and referenced the cancelled Navigator project as a casualty of that regulatory complexity. Other notable projects Minervini highlighted included the Prairie State Generating Station in Illinois, Minnkota Power’s Project Tundra in North Dakota, Linde’s hydrogen plant in Beaumont, Texas, which will capture nearly 2 million megatons of CO2 per year, and STRATO’s direct air capture facility under construction in Ector County, Texas, the latter two of which will be operational in 2025. Texas is a leader in developing storage resources, he added, and is developing three large storage hubs across the state. California has a lot of activity as well, particularly in the Bay area, according to Minervini. The state recently updated its climate goals, which include carbon neutrality by 2045, and recognition that CCS “a viable component in the pathway [to carbon neutrality],” Minervini said. The state has also passed some notable CCS-relevant laws in the past couple of years, he said, but is being cautious and “taking a surgical approach to its deployment.” Finally, from a global perspective, both point source CCS and DAC will be needed to reach net zero, according to Minervini. “We need to define the appropriate role for each of these technologies in our climate mitigation strategies, and it’s not going to look the same for every country,” he said, adding that corporations will likely not implement CCS unless there is a financial or regulatory incentive to do so. “We need to build our way to net zero,” Minervini concluded. “The energy transition really isn’t replacing technologies perse, it’s really adding to and building the infrastructure we need … building CCS networks, building transport and building storage infrastructure … and finally, any barriers to investment need to be addressed through policy development and appropriate market mechanisms.” Editor’s note: Before press time, the U.S. Internal Revenue Service issued long-awaited guidance of the tax credit, indicating that currently, GREET-based models do not currently satisfy the applicable statutory requirements for the SAF credit. However, the IRA advised that the U.S. DOE is currently collaborating with other federal agencies to develop a modified version of the GREET model that would satisfy the statutory requirements for the SAF credit. The agencies developing the modified GREET model currently anticipate its release in early 2024. Author: Anna Simet asimet@bbiinternational.com

BIOMASSMAGAZINE.COM 29

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Figure 1. Life cycle GHG emissions for forest residue-to-Fisher-Tropsch with totality of emissions and biogenic carbon neutral accounting system. Fisher-Tropsch diesel with carbon capture and storage achieves a negative carbon intensity score. IMAGE: LIFE CYCLE ASSOCIATES LLC

PATHWAYS FOR CARBON-NEGATIVE BIOMASS FUELS

BY ANNA REDMOND AND STEFAN UNNASCH

alifornia generates millions of tons of wood waste from its farms and forests annually, but less than 20% is repurposed for commercial use. The majority is left to decay in place or is burned, contributing to greenhouse gas (GHG) emissions and air pollution. Wildfire prevention efforts, which aim to reduce biomass fuel loads on one million acres of land each year, will exacerbate the state’s wood waste problem. Converting wood waste into biofuels can reduce overall emissions to the atmosphere. Utilization of biomass residues would not only avoid the negative impacts of current disposal practices, but also drive rural economic development, technological innovation and further emissions reductions by replacing fossil fuels. Renewable fuels such as hydrogen, biomethane, ethanol and sustainable aviation fuel are promising options for replacing conventional transportation fuels and reducing CO2 emissions. Adding carbon capture and storage (CCS) to these fuel production facilities can provide even greater carbon dioxide removal. Coproducing biochar can further reduce the emissions impact of a biofuel sys-

tem. Another approach involves the utilization of lignin to produce biomaterials or use as a petroleum bitumen substitute. Previous studies have explored the life cycle carbon intensity (CI) of various biomass-to-biofuel pathways, encompassing diverse feedstocks, technologies and end products, such as including wood waste to RNG via anaerobic digestion, biomass to electricity via pyrolysis, and woody biomass to sustainable aviation fuel via gasification and Fisher-Tropsch synthesis.

System Boundaries

Quantifying the CI or the amount of CO2e emissions per megajoule of a biofuel involves a comprehensive approach known as life cycle assessment (LCA). LCA evaluates the environmental impact of a product or process across its entire life cycle, from the extraction of raw materials to its eventual disposal. To gauge the CI of biofuels, an LCA begins by establishing baseline data and cataloging the energy and materials consumption of all involved processes, including carbon capture, transportation,

CONTRIBUTION: The claims and statements made in this article belong exclusively to the author(s) and do not necessarily reflect the views of Biomass Magazine or its advertisers. All questions pertaining to this article should be directed to the author(s).

32 BIOMASS MAGAZINE | ISSUE 1, 2024

Figure 2: Fuel Options with a Pathway to Negative Carbon Intensity Feedstock

Conversion Technology

Fuel

Carbon Storage

CI (gCO2e/MJ)

Forest Residue

Gasification + FT

Diesel

none

5 to 25

Forest Residue

Gasification + FT

SAF

CCS

< -50

Forest Residue

Gasification + PSA

Hydrogen

CCS

< -50

Forest Residue

Pyrolysis

Diesel

Biochar

< -50

Ag Residue

Gasification + FT, H2 Boost

SAF

CCS

< -50

Ag Residue

Fermentation

Ethanol

Lignin Product

< -50

storage and monitoring. Subsequently, they calculate the corresponding GHG emissions released into the environment. Finally, they assess the cumulative environmental effects within predefined system boundaries stemming from the biofuel system. In the case of a waste and residual biomass-to-biofuel system, system boundaries include biomass production and collection, including direct and indirect land use change; transportation of biomass to the facility; biomass preparation, including biomass chipping or grinding; biofuel production; CCS at biofuel production site; coproducts, such a biochar; fuel combustion in vehicle. In some cases, if the biomass were to be transported to an alternate disposal site in the baseline, the net difference for the transportation to the facility may be compared to the baseline and accounted for.

Carbon Intensity Calculations

To calculate the net CO2e emissions from a biomass-to-biofuel system, an LCA baseline must be established, which is a comparison of the greenhouse gas emissions from the biofuel project to the emissions from the biomass’ fate in the absence of the project. For example, if the biomass were left to decompose in the field, the baseline scenario would include the emissions from methane production. The timing of emissions in the LCA would also need consideration. For example, if the biomass decomposes over time, we should consider the cumulative emissions from the biomass over its lifetime. However, if the biomass decomposes quickly or combusts, we can safely ignore the timing of emissions. For this pathway example, we will consider only feedstocks that would have otherwise combusted, such as wildfire abatement residues or agricultural residues that would have been disposed of in burn piles. When biomass is burned, all the carbon that was sequestered is released into the atmosphere over a short period of time. This can be modeled as a single time pulse. The biogenic carbon released during burning is equal to the biogenic carbon that would be released from the biofuel during vehicle combustion. Therefore, the emissions from avoided burning and vehicle combustion cancel each other out, and the feedstock can be considered biogenic carbon neutral.

GHG Analysis

The GREET model considers various woody biomass feedstocks, such as forest residue and farmed trees. The life cycle GHG emissions for forest residue to FT diesel are shown in Figure 1, with two different accounting systems. First, all the carbon flows are shown, including the net biogenic uptake and CO2 released from the process. In the pathway without CCS, process emissions

plus fuel combustion equal the biogenic carbon into the process. GREET treats the net biogenic carbon flow as neutral, assuming that removal and additional growth balance. The RFS also requires that forest thinnings used for biofuel production result in increased growth of surrounding trees. When CO2 from processing emissions is stored, the net emissions are reduced. The biogenic process emissions are no longer emitted, and the net uptake results in a credit. Identical results are achieved with a biogenic carbon-neutral accounting system. The biogenic uptake credit is omitted, and stored CO2 is treated as a credit. The latter accounting system is represented for the well-to-tank emissions in the GREET model. CCS represents a significant fraction of the CI reduction and results in a very low CI. The extent of CCS is variable with the proposed process. For example, a lower level of CO2 storage could be achieved if only concentrated CO2 sources are captured. This approach would simplify CO2 recovery efforts. Also, grid power could be used to operate equipment. Both process changes would affect system complexity, cost and GHG emissions. The model is configured with a range of conversion pathways including gasification, pyrolysis and fermentation technologies. It examines numerous fuel pathways including hydrogen, FT diesel and jet, pyrolysis fuels, renewable natural gas and ethanol. GREET explicitly models CCS for several fuel pathways and treats the storage of organic residue from pyrolysis and anaerobic digestion as a storage credit. All the CO2 storage options provide a route for a carbon-negative pathway whether CO2 is stored as a gas, soil additive or other product. The factors influencing life cycle GHG emissions encompass energy inputs, yields and carbon storage strategies for biomass-to-fuel conversion technologies. Figure 2 presents a range of carbon-negative technologies, offering a basis for evaluating the impact of biomass conversion to fuels. Each technology includes parameters such as biomass-to-fuel yield, power consumption, natural gas consumption, carbon storage technology and carbon capture efficiency. The default approach in the GREET model accounts for Fischer-Tropsch conversion without any carbon storage. Other cases examined include gasification, pyrolysis and fermentation technologies. These methods produce a spectrum of fuels with varying strategies for carbon storage. The information presented in this table draws from an array of sources to provide comprehensive background details. These sources include the GREET model, ongoing project announcements, and scientific literature. Authors: Anna Redmond and Stefan Unnasch Life Cycle Associates www.lifecycleassociates.com

BIOMASSMAGAZINE.COM 33

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PELLET FUEL ESSENTIAL TO DECARBONIZATION GOALS

A strategy that is already well-developed will be part of the just and orderly transition to a decarbonized future. BY WILLIAM STRAUSS

here are many metrics showing that fossil fuel CO2 emissions are causing rapid changes in environmental variables, and the earth’s systems are unable to fully recycle CO2 emitted. Not only has there been steady warming, but in 2023, we may have crossed a tipping point that results in even more rapid change combined with increasing variability (more extreme highs and lows). If the future is going to be what we hope it will be, action is needed now.

Seeking a Just, Orderly and Equitable Solution

Today’s socioeconomic systems are based on the energy we derive from fossil fuels. Thus, the search is for “drop in” replacements that can continue to power the infrastructure we rely on with minimum disruption. There are already so-called drop in solutions that are being deployed in the power, heat and transport sectors. Energy-dense liquid fuels made from renewable feedstocks are gaining in use and coming down in cost. The use of ammonia and hydrogen (produced from renewable power) as non-carbon energy carriers will be part of the transition. Heating from sustainably sourced wood chips and wood pellets is commonplace in many EU countries and North America. However, power generated from wind and solar sources cannot be fully qualified as a drop-in because it is variable. Thus, no matter how many megawatts are deployed, sometimes it will generate less than the grid needs. Over the next few decades, it is likely that energy storage solutions will be developed and deployed at a scale that will sufficiently buffer intermittent and variable supply, and keep the power grids stable most (not all) of the time. But at least over the next few decades, to make the transition to a decarbonized future as

seamless as possible, the power grids will need CO2-beneficial generation that is on-demand and load-following. The use of pellet fuel produced from perpetually renewing biomass solves part of that problem. Existing coal-fueled utility power stations can, with relatively low cost and little downtime, make modifications and replace coal with pellet fuels produced from perpetually renewing (not depleting) sources. The result is renewable electricity that can be generated on demand.

Pellet Fuel: an Energy Dense Storage Solution

The idea that forests will be net-positive CO2 sinks forever is wrong. They will always reach saturation. But if well managed, they can be continuously used without lowering the net quantity of carbon they are storing. If the stock of biomass is not depleted over time, excess CO2 is not created and thus cannot accumulate in the atmosphere. For forest biomass, if the quantity of wood in the landscape is not depleted (i.e., the removal rates never exceed the growth rates) the quantity of CO2 released from any wood that is combusted is less than

or equal to the quantity of CO2 captured. This logic only works if the resource is continuously and perpetually renewing. Sustainability is the absolute necessary condition for the use of pellet fuels as a carbon beneficial coal replacement in power generation. The vast majority of the primary harvest of woody biomass for forest products industries is not for the production of pellet fuels. The primary users are sawmills (lumber, flooring, furniture, etc.) and pulp and paper mills (printing paper, cardboard boxes, toilet paper, etc.). These mills have been operating in some locations for more than a century because they only take in an amount of wood each year that is less than or equal to what grows in the working forests around them. The mills can, if well maintained, essentially operate forever. Properly managed pellet mills benefit from the same forest resource stewardship. What is the strategy for the multidecade transition that provides a seamless and low-carbon input to the power grid that can be baseload or load-following, and is available on-demand? We already have large-scale energy storage that can be part of the solution. The biomass

36 BIOMASS MAGAZINE | ISSUE 1, 2024

cycle captures solar energy and stores it. Forests are the world’s largest solar battery. Every year, about 5.7 x 1,024 joules of solar energy irradiates the earth’s surface. That solar energy is an essential part of our planet’s ecosystems. Plants and photosynthetic organisms utilize that energy to convert large amounts of CO2 into glucose. The chemistry of plant growth transforms the glucose into other sugars (hemicelluloses), cellulose, lignin and other plant matter. Every year, solar energy and photosynthesis convert billions of metric tons of CO2 and water into plant matter, and produce oxygen as a byproduct. A portion of that plant matter is trees. While some forests are not and should not be used to supply the forest products industry, many millions of hectares of forests are managed and cultivated to continuously produce logs for lumber, furniture and many other products that are part of everyday life. Those forests also produce wood chips for the manufacturing of paper, packaging, tissue and a variety of engineered wood products. Some of the byproducts of sawmills and the parts of the rest of the trees that are not suitable for higher value use may find their way to pellet factories to produce solid fuel, and to factories that create renewable liquid fuels from cellulosic feedstock. These managed, working forests are, in effect, tree farms. Each plot on these tree farms cycles through stages of regeneration, growth to maturity and harvest. But in aggregate, as long as the rates of removal never exceed the rates of growth, the total quantity of wood (and thus stored carbon) does not decline. The average growth rate of forests around the world is about 12 metric tons (mt) per hectare per year. In northern regions it is less, and in some tropical locations with fast-growing tree species, it is more than 20 mt per hectare per year. Forests cover approximately 31% of the world’s land surface, about 4 billion hectares. Assuming an average growth rate of 12 mt per hectare per year and an average energy content per mt of about 8.64 gigajoules (GJ) (based on wood with a moisture content of 50%), the world’s forests store about 415 billion GJ, or 115 million gigawatt-hours (GWhs) per year. Estimates indicate the total electricity produced by wind and solar in 2022 was about 3.5 million GWh. The forests capture and store about 33 times as many GWh per year as all solar and wind combined. In ad-

dition, nearly all of the power generated by solar panels and wind turbines is consumed as it is produced. Without storage, solar and wind power are not dispatchable, whereas the solar energy captured by the world’s forests is stored. Clearly, only a portion of the world’s forests are used to supply the forest products industries—about 30%, according to the FAO. Based on the estimate of how much of total North American primary harvest becomes pellets—4.5%—and using that proportion to estimate global GWh that could be in pellet fuel, more than 1.55 million GWh could be moved from forest storage into pellet fuel every year without depleting forests and the carbon stock held in the forests. BloombergNEF forecasts that there will be about 1,880 GWh of long-duration energy storage by 2030. Based on forests that are already managed for producing wood for lumber, paper, etc., and only using 4.5% of that material to produce pellet fuel, there is potential today for pellet fuel to deliver 826 times more stored energy per year than all of the energy storage solutions forecast for 2030. If bioenergy carbon capture and storage (BECCS) is added to the analysis, that stored energy is not only put to use to help keep the electricity grids stable, but the stored carbon is permanently removed from the atmosphere.

Beginning of the End of the Fossil Fuel Era

There is already a pathway that can support decarbonization goals, and it’s deployable now. In 2022, the global pellet fuel supply chain filled the equivalent of a Panamax-size ship (about 65,000 mt) every day of the year with stored energy in the form of carbon beneficial pellet fuel. On the demand side, large utility power stations have successfully completed “bioconversions.” For them, coal is history; dispatchable or baseload generation is not. The orderly transition from today to the desired future should include policies that support the responsible use of solid fuel derived from the stored solar energy in renewing biomass. There is nowhere close to enough renewable sources of biomass in the world to replace all the coal that is being used—but there is enough to make a significant difference. Author: William Strauss President, FutureMetrics Inc. williamstrauss@futuremetrics.com

BIOMASSMAGAZINE.COM 37

A Nel Hydrogen containerized PEM Electrolyser IMAGE: CONSTELLATION ENERGY CORPORATION

CONTAINERIZED ELECTROLYSERS: ENABLING RAPID DEPLOYMENT OF SAF PRODUCTION FACILITIES

The single largest-volume raw material in SAF production, the carbon intensity of hydrogen is a key consideration for SAF producers. BY LYNN GORMAN

hose in the hydrogen generation business are enthused about the supply and demand situation for sustainable aviation fuel (SAF). According to David Wolff, director of industrial product sales at Nel Hydrogen, the hydrogen market is hyped up right now, fueled by new U.S. government initiatives—the Inflation Reduction Act, for one—and the establishment of hydrogen hubs. All this attention has created a sort of “gold rush” mentality surrounding all things hydrogen. While it is breathtaking, it also warrants caution by stakeholders to focus on practical hydrogen applications now and in the foreseeable future. “SAF is an outstanding example of a business that makes sense now,

and the momentum is building quickly,” Wolff says. There are various routes to make SAF, but all SAF raw material options require hydrogen to modify feedstock and biomass molecules into complex hydrocarbons suitable for aviation fuel. SAF will require massive production of hydrogen, and that new supply of hydrogen must be made in a manner that meets the standard for sustainability—essentially, no net fossil carbon can be added to the environment. The Inflation Reduction Act differentiates “green” hydrogen, which is made from renewable energy, and typically would be solar, wind or hydro from “clean” hydrogen, which includes hydrogen made from nuclear electric-

ity. Together, both renewable and nuclear power satisfy the sustainability requirements to feed electrolytic hydrogen generation, which uses electricity to crack water, or H2O, into clean hydrogen and byproduct oxygen. Hydrogen made via the electrolysis process is of particular interest to produce clean hydrogen for SAF production because electrolysis is highly scalable, according to Wolff. “It’s a challenge to make a small steam methane reformer to make hydrogen from natural gas,” he says. “But electrolyser technology scales relatively easily.” There are electrolysers already commercially available that range from the size of a coffee cup up to many tons of capacity per day

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HYDROGEN¦ of capacity. There is an experienced electrolyser supplier base, which minimizes the technology risk for SAF producers. There are also a large number of electrolysers operating today. And, perhaps most importantly for the overarching goal, there are no carbon emissions from the process, as long as the energy feedstock does not generate carbon emissions. Further, on the cost side of the ledger, electrolysis enables monetizing excess and low-value electricity supplies, and that has encouraging potential for both stranded renewable energy and nuclear energy that is too expensive to sell at a profit. For example, there are periods of time in the middle of the afternoon when there is excess solar power. There is excess wind power on certain days, especially during the winter months when capacity factors are high and cooling loads are low. Nuclear plants contend with excess energy above grid needs almost every night. Electrolysis is uniquely compelling to the nuclear power economics by creating profitable nighttime electricity markets. Those plants can create hydrogen all night long and feed the grid all day long. And in doing so, a nuclear power plant can serve two profitable markets. Finally, the U.S. Treasury is releasing guidelines under which the deployment of electrolysis will incentivize clean energy investments for the production of low-carbon hydrogen. According to the International Air Transport Association, the global aviation industry is set to require 120 million metric tons (mt) of clean hydrogen a year by 2050, with 100 mt to produce SAF and 20 mt for H2-powered aircraft. So, 100 million mt of clean hydrogen a year for SAF by 2050 equals 274,000 mt per day of hydrogen production. Carrying this math through, 274,000 mt per day of hydrogen would entail about 650,000 MW of electrolysis hydrogen production. There are two types of electrolysis systems that are generally considered commercially mature right now. One is alkaline electrolysis, and the other is proton exchange membrane (PEM) electrolysis. There are other types in development that also show promise. Alkaline technology has historically been used for large-capacity hydrogen plants. Alkaline cell stacks costs less on a per-kilowatt basis because they do not use precious metals as catalysts as PEM does, and alkaline equipment has been commercially deployed for almost a century. Conversely, PEM electrolysers are compact, and can ramp quickly with variable energy sources. They can also achieve a similar range

of hydrogen production from pounds per day to hundreds or thousands of tons per day. PEM electrolysers have been working in the field commercially for about 50 years. Electrolysis begins with the electrolyser’s cell stack. That’s the engine of the electrolyser, akin to the chip in a computer. Every cell stack is made up of many electrolytic cells, each of which is an electrochemical reactor. Add water, an electrolyte and DC power, and it creates hydrogen and byproduct oxygen. “The cell stack gets surrounded by what we call the balance of plant (BOP),” Wolff says. “BOP can be supplied by the electrolyser maker, or it can be supplied by an engineering, procurement, construction (EPC) contractor, or perhaps another third party. As companies scale up electrolysis, the number of cell stacks also multiply. Cell stacks scale linearly, while shared BOP may be scaled by using ever larger vessels. The BOP is where experts such as EPC contractors can best use their expertise to drive cost reduction in the plant. These include electrical and water supply, controls and safety management, water and oxygen gas management, hydrogen purification and compression, and heat management. According to Wolff, PEM is best suited to small footprint applications and offers simple, straightforward equipment that does not require downstream compression or gas purification. It is this equipment, he believes, that will be used for the initial stages of the SAF production journey. “Currently, Nel PEM containerized systems are capable of producing up to 1 ton a day of hydrogen,” Wolff says. “Soon, that will be higher than 1 ton a day as development continues. Further, taking the same PEM stack technology, and packaging it innovatively, we will provide cell stack subsystems that can produce four tons a day.” PEM stack modules, which are containerized cell stack systems, along with a shared BOP in larger hydrogen systems, can produce several tons of hydrogen each day. Alternatively, the largest plants might omit containerization and be placed in buildings using bare, uncontainerized cell stacks in groups of dozens to create even larger-scale hydrogen production. The cell stacks can be arrayed in a number of different configurations. “The point is as the plant gets bigger, more and more cell stacks can be serviced together with shared BOP,” Wolff adds. The advantages of containerized PEM electrolysis are several. They include predictable availability. The equipment is made in a factory;

it is not assembled in the field. There are minimal technology and supply chain risks. There are also minimal infrastructure requirements in the field. Basically, the needs are deionized water, electricity, the ability to dispose of waste water, and the customer hydrogen header pipe to take the produced hydrogen. Highly skilled tradespeople are not necessary to do field fabrication, and systems can be installed in any weather season. Because the systems are highly standardized, companies receive an assured level of support from manufacturers that have made hundreds of such systems. It is believed that PEM electrolysers, at least initially, will play the larger role when coupling to renewable energy grids because their ability to respond instantly to electrical supply changes and downstream process needs. “There is even innovation happening right now for hydrogen-using companies to consider employing a blend of alkaline and PEM systems,” Wolff says. “For instance, if you wanted 100 MW of electrolysis capacity, lowest possible deployed cost, and the ability to ramp up and down to meet a certain amount of renewable energy, then you might deploy 70% alkaline and 30% PEM. That would give you the lowest deployed cost because alkaline systems are less expensive to buy and are slightly more electrically efficient. Meanwhile, the PEM portion of the plant can dynamically track the ups and downs of the electrical supply.” To match the ramp-up of hydrogen needs for the SAF market and others, the electrolysis industry is investing to meet these growing needs. “The priority as equipment makers is increased cell stack production,” Wolff says. “We are also making significant headway to achieve a lower cost per unit of capacity.” The industry is also working to achieve wide geographic servicing because SAF will be made all over the world using local feedstocks whenever possible. As an example, Nel is building new electrolyser equipment manufacturing plants in Europe and a new factory near Detroit, Michigan. When fully developed, the Detroit plant alone will have a production capacity of up to 4 GW alkaline and PEM electrolysers. Hydrogen is the single largest-volume raw material in SAF production; hence hydrogen carbon intensity is a key consideration for SAF producers. Hydrogen made via zero-carbon electrolysis is a viable solution. Author: Lynn Gorman On behalf of Nel Hydrogen

BIOMASSMAGAZINE.COM 39

Catalytic ceramic filters combine the advantages of ceramic filters with an incorporated active selective catalytic reduction catalyst for the removal of nitrogen oxide, dioxin, sulfur oxides and volatile organic compounds. IMAGE: PRECISION PARTNERS

CATALYTIC CERAMIC FILTERS FOR BIOMASS POWER PLANT FLUE GAS TREATMENT

Catalytic ceramic filters can be an excellent solution for large biomass boilers and many other industrial applications. BY IAN CHISEM

ith the continuous efforts to reduce the air pollution by raising emission standards in many countries, catalytic ceramic filters (CCF) are increasingly employed to meet more stringent regulatory emission requirements due to their technical and commercial advantages, such as very high pollution removal efficiency, simple and compact system design and low operational expenditure. Zhengyang biomass power plant, owned by China Energy Group, chose CCF to remove particulate matter (PM), acid gases, sulfur oxides (SOx) and nitrogen oxides (NOx). The power plant was commissioned in December 2020.

Background

Zhengyang biomass power plant has one 130-ton-per-hour natural circulation boiler using a vibrating grate. The electricity generation capacity is 35MWe. The main fuels are corn stover, wheat straw and peanut shells. Owing to the characteristic of the biomass fuels, particuarly the high moisture content in the flue gas of 21% volume, could cause serious acid corrosion of the facilities working at lower operational temperatures. The dust load in the flue gas is 15,000 milligrams per normal meter cubed (mg/Nm3 ), representing the design value for the PM removal system, with a high content of alkali metals such as potassium and sodium.

The flue gas treatment system was designed to meet an extra low emission requirement, which mandated the pollution limits (6% O2) as PM <10 mg/Nm3, sulfur dioxide (SO2) <35mg/Nm3, NOx <50mg/ Nm3.

Conventional Flue Gas Treatment Processes

Conventional techniques for removing the three regulated pollutants (PM, SOx and NOx) to meet emission requirements have their limitations and disadvantages. For PM removal, fabric filters will have the issue of ammonium bisulfate (ABS) deposition at their working temperature range, which can cause high pressure drop

40 BIOMASS MAGAZINE | ISSUE 1, 2024

EMISSIONS¦

and even blind the filters, since the SCR system and ammonia injection are upstream of the baghouse. The slipped ammonia (NH3) reacts with sulfur trioxide (SO3) present in the flue gas to form ammonium bisulfate. Due to failures caused by physical and chemical attacks, fabric filters generally need to be replaced every two to three years, depending on the operating conditions. Electrostatic precipitator (ESP) technology is another widely used dust removal technique, which cannot reliably achieve PM removal to less than 10 mg/Nm3. For NOx reduction (deNOx), selective noncatalytic reduction (SNCR) has limited deNOx efficiency and cannot attain the required NOx emission value. To avoid reheating flue gas, selective catalytic reduction (SCR) is mostly performed in a temperature window between 572 to 752 degrees Fahrenheit (300 and 400 degrees Celsius), with the dust in the flue gas having direct contact with the catalyst. Alkali metals and heavy metals may poison the catalyst and can result in premature catalyst failure. In general, the catalyst needs to be regenerated regularly and replaced every three to five years. For desulphurization, techniques such as wet flue gas desulphurization, semi-dry scrubbing and dry desulphurization are available for the flue gas treatment. The wet and semi-dry processes will cause excessive heat loss from the flue gas, which lowers the system heat efficiency. The wet process consumes copious amounts of water and produces correspondingly large amounts of wastewater, which requires additional treatment facilities. For the dry processes, the deSOx efficiency increases with temperature in the range of 482-752 degrees F for the lime-based reagent. Where fabric filters are used for PM removal, the deSOx efficiency cannot reach its maximum range because of the lower working temperatures of fabric filters.

Advantages of Catalytic Ceramic Filters

Catalytic ceramic filters, first developed by Clear Edge, combine the advantages of ceramic filters with an incorporated active SCR catalyst for the removal of NOx, dioxin, SOx and VOCs. Catalytic ceramic filters are used in filter plants in much the same way as bag filters, albeit at higher temperatures. The low-density ceramic filters can

Table 1: Input Data for the Flue Gas Treatment System Design Items

Unit

Values

Flue gas flow rate

Nm3/h

177,233 (wet)

Inlet temperature

Degrees Celsius

320-350

Inlet SO2

mg/Nm3

≤1000 (dry,6% O2)

Inlet NOx

mg/Nm3

≤1000 (dry, 6% O2)

Moisture content

% vol

21.31

O2 content

% vol

4.03

Inlet dust

mg/Nm3

15,000

Figure 1: Flow chart of the flue gas treatment system of Zhengyang Biomass power plant.

typically be used in the 356 to 842 degrees F range, depending on the catalyst type. Following almost 20 years of successful deployment in industrial air pollution control systems, the advantages of a flue gas treatment system using catalytic ceramic filters have been found to include the following.

• Simultaneous removal of PM, NOx, SOx and dioxin from flue gas. • Effective handling of submicron particles in industrial gas processes with the capability to filter gas to limits of less than 2 mg/m3. • Superior deNOx efficiency of greater than 95% and long lifetime of catalyst longer than five years, since the catalyst is

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¦EMISSIONS

through economizer stage two, air preheater and heat recovery. For the heat exchangers downstream of the catalytic ceramic filters, the operation conditions are optimal because the flue gas is cleaned, which prevents acid corrosion, dust erosion and dust accumulation and blockage. This considerably reduces not only the operation cost due to a lower pressure drop, but also maintenance costs for these heat exchangers. Moreover, the design flue gas velocity flow through these heat exchangers could be increased, as the flue gas is virtually dust free, the heat transfer becomes more efficient and thus, the required heating surfaces are reduced, which means that the cost for the heat exchangers decreases.

Table 2: Emissions at the system outlet Pollutants

Unit

Measured Values

Prescribed Limit

mg/Nm3 at 6%O2

1.03-1.62

<10

SOx

mg/Nm3 at 6%O2

11-14

<35

NOx

mg/Nm at 6%O2

31-36

<50

embedded within the filter walls, hence it is protected from dust deposition and poisoning by heavy metals. • No ammonium bisulfate deposition on the catalytic ceramic filters, as the operational temperature is higher than its dew point of around 446 degrees F. • Low system pressure drop-in comparison to a conventional SCR and baghouse. • Resistant to corrosion and erosion; nonflammable, so no risk of ignition from sparks of biomass particles. • Modular design—one filter module at a time can be isolated for maintenance without interrupting operation. • Long service life: five to 10 years operating life of the catalytic filter elements. • CAPEX savings: simplified equipment train with less equipment for PM, NOx and SOx removal. • OPEX savings: reduced operation and maintenance costs, less equipment to maintain, increased uptime and long service life of the filter element and catalyst.

System Concept of Flue Gas Treatment

To avoid the disadvantages of the usual flue gas treatment processes and to take advantage of catalytic ceramic filters, the inlet 42 BIOMASS MAGAZINE | ISSUE 1, 2024

temperature of flue gas treatment system was set to 608 to 662 degrees F. The boiler heating surface economizer was therefore split into two stages, such that the outlet gas temperature of the first stage lies exactly in this temperature range. The input data for the flue gas treatment system design are listed in Table 1. The flue gas treatment system for Zhengyang biomass power plant consists mainly of a dry desulphurization scrubber, settling chamber and catalytic ceramic filter housing. The settling chamber was designed to remove most sparks and large-size particulates. The catalytic ceramic filter housing consists of 12 filter modules with a total of 5,040-piece, 3,000-millimeter filter elements supplied by Clear Edge. The modular design allows for cut-off of one module for maintenance without interrupting operation. In the catalytic ceramic filter housing, PM including heavy and alkali metals, desulphurization reagent powder and NOx are simultaneously removed with extremely high efficiency. The flue gas discharged from the catalytic ceramic filters is cooled down to 230 degrees F after running successively

System Performance

The flue gas treatment system with catalytic ceramic filters demonstrates high performance and reliability since the plant commissioning in December 2020. The emission values measured three months after commissioning are shown in Table 2. The measured emission values show that the target emission values for the system design were completely achieved, demonstrating high efficiency for the pollutants removal.

Conclusions

Zhengyang biomass power plant is the largest biomass plant in China that utilizes catalytic ceramic filters for flue gas treatment. The catalytic ceramic filter solution stood out from alternative competing concepts. The owner of the plant was convinced by a series of economic, operational and technical advantages offered by CCF technology. The success of the catalytic ceramic filter installation proves that they are an excellent solution even for large biomass boilers, as well as many other industrial applications. Clear Edge and the Zhengyang biomass power plant contributed to this article. Author: Ian Chisem Technical Director, Ceramic Filter Alliance Ian.chisem@ceramicalliance.com

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