A technical decision only delivers impact when the fuel pathway is robustly underpinned.
Limited volumes, heterogeneous production routes and high demand.
Low-cost offers without proof of origin are strategically risky.
Treat sourcing as a long-term supply chain strategy.
Green methanol is not a uniform product. There are several production pathways that differ considerably in energy source, feedstock, carbon balance and cost. For operators, this differentiation is not academic – it determines whether the purchased fuel is actually credited as emissions-reducing under FuelEU Maritime and EU ETS.
The best-known route is the electro-methanol pathway (e-methanol): green hydrogen is produced through electrolysis with renewable electricity and then synthesised with CO₂ to form methanol. The CO₂ source is decisive. If the CO₂ comes from direct air capture (DAC), the methanol is considered largely climate-neutral. If it comes from an industrial point source – such as a cement works – the climate balance is debated, as the CO₂ would have been produced regardless.
A second path is the bio-methanol route: organic residues such as sewage sludge, wood waste or agricultural by-products are gasified or fermented, first producing a synthesis gas that is then converted to methanol. This route can be less expensive than e-methanol but is limited in available quantity by the feedstock base.
A third, less discussed pathway is the combination: bio-CO₂ (from biogas upgrading) is synthesised with green hydrogen to produce methanol. This route combines the advantages of both pathways but requires both available biomass and renewable electricity.
Costs vary significantly. E-methanol currently sits at approximately 800 to 1,500 USD per tonne, depending on electricity costs and plant scale. Bio-methanol moves in the range of 400 to 900 USD per tonne. For comparison: conventional grey methanol from natural gas costs roughly 250 to 400 USD per tonne. The price premium for green methanol over conventional HFO (around 400–600 USD/t) is therefore substantial and must be factored into every business case.
A frequently overlooked technical aspect is purity. Maritime methanol engines are sensitive to contamination – particularly higher alcohols, water and organic acids that can occur as by-products in certain bio-methanol production routes. The ISO 9948 specification defines purity requirements, but not all producers consistently meet them. Operators must therefore establish their own quality controls during bunkering.
Procuring green methanol is not merely a question of price and quantity but also one of proof of origin. Under FuelEU Maritime, operators must demonstrate that the fuel used meets the required emissions reduction targets. This demands end-to-end documentation of the production pathway – from feedstock through energy source to the finished methanol.
In practice, this means that long-term contracts with producers must specify not only delivery volumes and prices but also certification requirements. The International Sustainability and Carbon Certification (ISCC) has established itself as a common standard, but parallel systems exist – and regulatory recognition varies by jurisdiction.
A further practical problem is the physical supply chain. Green methanol is currently produced at a limited number of locations worldwide – primarily in Northern Europe, South America and China. Port infrastructure for methanol bunkering is growing, but not all ports on the major trade routes can yet offer green methanol. Operators therefore face a choice: either bunker at the few ports with availability and plan the route accordingly, or use conventional methanol as a fallback – with the corresponding consequences for the emissions balance.
The question of book-and-claim systems (mass balancing) is becoming increasingly relevant. Similar to green electricity, a system could emerge in which the physical methanol need not be green, provided the corresponding quantity is produced and certified elsewhere. However, the regulatory acceptance of such models has not yet been conclusively resolved.
As of 2026, there are a handful of operational production facilities for green methanol with maritime relevance. The best known is the European Energy plant in Denmark, producing e-methanol from wind power and biogenic CO₂. In China, several projects have commenced production, though the verification of actual green quality is difficult in some cases.
Rotterdam has positioned itself as the first European methanol bunkering hub, with dedicated infrastructure and supply agreements. Singapore is working on comparable capacities but remains in the build-up phase. For other important ports – Shanghai, Busan, Tanger Med – projects have been announced, but timelines are uncertain.
Total production capacity for green methanol currently sits far below the demand that the existing methanol dual-fuel orders alone will generate. This gap between supply and demand is expected to narrow in the coming years but will not close. Operators must therefore reckon with a market in which green methanol will remain a scarce commodity for some time.
A robust sourcing strategy for green methanol should encompass the following elements:
Supplier diversification: Do not rely on a single producer. Secure at least two supply sources with different production pathways.
Contract duration: Long-term contracts (5–10 years) with price adjustment clauses offer planning certainty but also loss of flexibility.
Quality assurance: Own bunker analyses at every delivery, not merely reliance on certificates.
Regulatory monitoring: The crediting rules for green fuels are constantly evolving. A dedicated process for monitoring regulatory developments is necessary.
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