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The headline is based on a real project, but manure does not go straight into a machine and come out as hydrogen. At a Washington dairy digester, organic waste is first broken down into methane-rich biogas. Modern Hydrogen’s proposed next step is to split that methane into hydrogen and solid carbon. The approach is technically plausible; publicly available information does not establish that the original dairy installation achieved sustained commercial-scale output or a verified climate benefit.
What was the Washington project?
The project joined Qualco Energy, the Tulalip Tribes, Werkhoven Dairy and a startup then called Modern Electron, now Modern Hydrogen. Founded in 2015 and spun out of Intellectual Ventures, the company initially focused on recovering heat from furnaces and water heaters to generate electricity before expanding into methane pyrolysis and distributed hydrogen. GeekWire reported in April 2022 that the company had raised about $70 million in venture capital by that point; that is a historical figure, not a current funding total. GeekWire’s 2022 report also described a $769,360 state grant for the project.
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The planned system would use methane from Qualco’s anaerobic digester as feedstock for hydrogen production, with the hydrogen intended for local use. The 2022 report said the pilot was expected to be operating by early 2023. That was a target, not confirmation of completion. Later company and government material documents other Modern Hydrogen pilots and projects, but the available sources do not verify sustained operation or commercial-scale hydrogen production at Qualco.
How manure becomes hydrogen
The process has two distinct stages: digestion makes biogas from organic waste; pyrolysis then separates methane in that gas into hydrogen and solid carbon.
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- Digestion: Microorganisms break down manure and food waste without oxygen in an anaerobic digester. The output includes methane-rich biogas and digestate, the remaining nutrient-containing material.
- Gas preparation: Biogas can contain carbon dioxide, water vapor, hydrogen sulfide, siloxanes and other impurities. Gas cleanup may be needed to protect equipment and meet the requirements of the next process.
- Methane pyrolysis: Heat is used in the absence of oxygen to split methane into hydrogen and solid carbon:
CH₄ → C + 2H₂. Modern Hydrogen describes its systems as converting natural gas, renewable natural gas or biogas into hydrogen and solid carbon onsite. The company’s process description explains its intended feedstocks and applications; TNO’s methane-pyrolysis overview provides a general explanation of the technology. - Use and handling: Hydrogen can be used in fuel cells, burned in suitable equipment, blended into gas infrastructure where permitted, or supplied to industrial users. The solid carbon must also be handled and either sold, incorporated into a product, stored or otherwise managed.
Digestion does not eliminate all manure-related materials: digestate, water, nutrients, pathogens, odors and possible contaminants still require responsible management.
Reported digester throughput figures differ by source and description. GeekWire reported roughly 60,000 gallons of manure plus 24,000 gallons of food waste per day in 2022. Modern Hydrogen later described about 85,000 gallons per day of manure and food waste combined at the Werkhoven Dairy digester. These are reported figures from different accounts, not a single definitive capacity measurement. Modern Hydrogen’s account of the dairy project gives the later figure.
How pyrolysis differs from other hydrogen routes
| Route | What it does | Key distinction |
|---|---|---|
| Methane pyrolysis | Splits methane into hydrogen and solid carbon. | It avoids forming carbon dioxide as the direct carbon product, but still requires process energy and management of the solid carbon. |
| Steam-methane reforming | Uses methane and steam to make hydrogen. | It normally produces carbon dioxide unless carbon capture is added. |
| Water electrolysis | Uses electricity to split water into hydrogen and oxygen. | Its climate impact depends substantially on the electricity source. |
| Biogas or renewable natural gas use | Uses digester gas directly for energy or upgrades it for gas-grid use. | It is an alternative use for captured methane, not a hydrogen-production step. |
Biological hydrogen production and gasification are different routes again: one relies on biological processes, while the other turns solid biomass or waste into a mixed gas. A farm or utility would need to compare these options with direct biogas use or renewable natural gas, rather than assume hydrogen is automatically the best destination for digester gas.
Why capture manure methane—and what “clean-burning” means
Manure can release methane if it is not managed in a way that captures the gas. Because methane is a potent greenhouse gas, a digester can offer a benefit by collecting it for productive use. The hydrogen proposal adds another step: rather than simply burning the biogas in a generator or upgrading it to renewable natural gas, it seeks to extract hydrogen while leaving carbon as a solid coproduct.
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When hydrogen itself is burned, it produces water rather than carbon dioxide from the hydrogen molecule. That narrow point does not establish that the complete system is zero-emission, carbon-negative or even low-carbon under a particular accounting standard. The result depends on the full chain:
- Methane leakage: Leaks from manure handling, digestion, gas cleanup or equipment can erode the climate benefit.
- Heat and electricity: Pyrolysis requires heat, and the source and amount of process energy affect emissions and efficiency.
- Feedstock baseline: The comparison changes depending on whether methane would otherwise escape, be used in a generator, or be upgraded to renewable natural gas.
- Carbon fate: Solid carbon provides a climate benefit only to the extent it is durably retained rather than later oxidized or released.
- Combustion conditions: Hydrogen combustion can generate nitrogen oxides at high temperatures, depending on the equipment and operating conditions. Fuel cells avoid combustion-related NOx but require cleaner hydrogen.
For those reasons, “hydrogen made from captured dairy biogas” or “methane-pyrolysis hydrogen” is more precise than calling this project “green hydrogen.” Color labels are inconsistent; a low-carbon claim should be tied to a defined standard and lifecycle analysis.
The solid carbon is both an opportunity and a constraint
Making solid carbon rather than carbon dioxide is a central feature of methane pyrolysis, but producing a solid is not the same as proving permanent carbon removal. The carbon needs a dependable market or storage route, quality controls and credible accounting. Material incorporated into asphalt may be retained for a useful period, but product use, durable storage and verified removal are not interchangeable claims.
Modern Hydrogen currently emphasizes incorporating captured carbon into asphalt and infrastructure materials. In May 2024, NW Natural and Modern Hydrogen publicly unveiled a Portland project that was producing hydrogen and capturing solid carbon; the hydrogen was blended with natural gas and delivered through existing infrastructure, and the carbon was incorporated into asphalt products. NW Natural’s announcement describes that installation. It is evidence of a separate deployment, not proof that the Qualco dairy project succeeded commercially.
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The original Qualco coverage discussed possible agricultural use of the carbon. Pyrolysis carbon is not automatically fertilizer: agricultural use would depend on its composition, contaminants, agronomic performance and regulatory approval. A carbon outlet that works technically may still be too small, costly or unreliable to support a commercial business.
What is established about performance?
The most important missing public figures for the Qualco project are its actual hydrogen output, methane conversion rate, energy consumed per kilogram, hydrogen purity, uptime, carbon yield, cost and measured lifecycle carbon intensity. Without those data, it is not possible to determine whether the installation delivered a reliable, economical or lower-emission fuel supply.
Modern Hydrogen told the California Energy Commission in 2024 that pilot projects were operating in Oregon, Florida and Washington. The company also described a modular product in development capable of producing 500 kilograms of low-carbon-intensity hydrogen per day in a filing attachment. The 500-kilogram figure is a company product-development claim, not a measured output for the Qualco dairy system. The California Energy Commission filing and the filing attachment should be read as company representations, not independent performance verification.
A pilot announcement, a unit capable of producing hydrogen, continuous operation, independently measured performance and profitable repeatable deployment are different milestones. The public record described here supports continuing demonstrations and development, not a conclusion that manure-derived hydrogen has become a mature, low-cost commodity.
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What still has to work technically and economically?
Gas quality and hydrogen purity
Biogas composition varies, and contaminants may require removal before pyrolysis. Hydrogen for a fuel cell has stricter purity requirements than hydrogen used in some combustion applications, so an intended end use affects the cleanup and verification needed.
Heat, reactor operation and carbon handling
Methane pyrolysis operates at high temperature. The original project report noted the challenge of running the reaction efficiently and its energy demand. Carbon can build up in reactors, affect heat transfer and create a material-handling burden. A workable system needs dependable operation as well as an outlet for the carbon.
Variable feedstock and utilization
Manure volume and digester gas quality depend on the farm, herd, food-waste inputs and digester performance. A project must maintain steady feed and high equipment utilization despite those variations.
Costs and competing uses
The financial case depends on hydrogen revenue, carbon value or disposal cost, gas cleanup, process energy, equipment utilization, grants or policy credits, avoided transport and the value of competing options such as direct biogas use, renewable natural gas and electrolysis. A peer-reviewed economic discussion of methane pyrolysis notes the importance of monetizing the solid-carbon coproduct, particularly where carbon pricing is absent. The analysis is available here.
Best Value
For an actual site, the relevant comparison is not simply hydrogen versus fossil fuel. It is whether the added pyrolysis equipment and energy produce more value and lower lifecycle emissions than the farm’s realistic alternatives for captured digester gas.
How the broader field has developed
Modern Hydrogen’s Portland project and its reported pilots show that the company continued developing distributed methane-pyrolysis systems after the Qualco announcement. Separately, the U.S. Department of Energy selected dairy- and organic-waste-to-hydrogen work for feasibility and demonstration funding. Its dairy project summary describes evaluating environmental and economic feasibility through modeling, lifecycle analysis, scalability and financial metrics—work that signals open questions rather than a completed commercial solution. The DOE dairy project summary and the DOE waste-to-fuels selections describe those efforts. The latter lists a $750,000 award to the California Dairy Research Foundation project and other organic-waste studies.
These projects make dairy-methane hydrogen an active research and demonstration area. They do not show that it is already an established commodity or that every manure-to-hydrogen design will deliver the same emissions or economics.
When might manure-derived hydrogen make sense?
The approach is most plausible where a site already has a digester, can reliably clean and supply biogas, has a nearby hydrogen user, and can manage or sell the carbon coproduct. Onsite production may avoid the cost and complexity of transporting hydrogen, especially where an industrial or utility customer can use it. But a farm should compare the full system against direct biogas use and renewable natural gas, including the opportunity cost of diverting methane from existing energy uses.
A credible project assessment would need measured digester and gas-quality data, hydrogen offtake, carbon offtake, permitting and safety review, lifecycle accounting, process-energy requirements, uptime assumptions and a financing model. Until such figures are available for the specific installation, the Washington project is best understood as a promising but incompletely documented pilot concept—not proof that cow manure is already being turned into commercially successful clean fuel.
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