Trend analysis: Hydrogen & e-fuels — where the value pools are (and who captures them)

The global hydrogen economy is projected to reach $642 billion by 2030, yet only a handful of value pools will generate outsized returns. Green hydrogen production costs have fallen 40% since 2021, crossing below $4/kg in optimal locations, and e-fuel offtake agreements now exceed 15 million tonnes of committed annual capacity by 2030. Understanding where margins concentrate and which players capture them is the difference between investing in transformative infrastructure and funding stranded assets.

Why It Matters

Hydrogen and e-fuels sit at the intersection of decarbonization mandates and hard-to-abate industrial demand. Aviation, shipping, steelmaking, and ammonia production collectively represent over 30% of global CO₂ emissions, and direct electrification cannot reach most of these sectors. Policy tailwinds are accelerating: the EU Hydrogen Strategy targets 10 million tonnes of domestic green hydrogen production by 2030, the US Inflation Reduction Act offers up to $3/kg in production tax credits, and the UK Hydrogen Strategy commits GBP 240 million to the Net Zero Hydrogen Fund. The result is a market where value creation is shifting rapidly from upstream production toward midstream infrastructure and downstream application integration.

Key Concepts

Green hydrogen is produced via electrolysis powered by renewable electricity. Production costs range from $3.50 to $6.00/kg depending on electricity prices and electrolyzer utilization rates.

Blue hydrogen uses natural gas with carbon capture and storage (CCS). Costs range from $1.50 to $3.00/kg but face scrutiny over upstream methane leakage and CCS capture rates averaging 90-95%.

E-fuels (electrofuels or synthetic fuels) combine green hydrogen with captured CO₂ to produce liquid hydrocarbons, methanol, or ammonia. These drop-in fuels can use existing distribution infrastructure.

Levelized cost of hydrogen (LCOH) is the benchmark metric for comparing production pathways. It includes capital expenditure, electricity costs, capacity factor, and stack replacement.

Offtake agreements are long-term contracts between hydrogen producers and industrial buyers that underpin project financing. Typical terms run 10-15 years with price escalation clauses tied to carbon pricing or electricity indices.

What's Working

Electrolyzer manufacturing scale-up

Global electrolyzer manufacturing capacity reached 35 GW annually in 2025, up from 8 GW in 2022. This scale-up is driving unit cost reductions of 15-20% per year for both alkaline and PEM (proton exchange membrane) systems. Nel Hydrogen's facility in Heroya, Norway, produces 500 MW of alkaline electrolyzers annually and has contracted 2.2 GW of orders through 2027. ITM Power's Bessemer Park facility in Sheffield produces 1.5 GW of PEM electrolyzer capacity per year with module costs below $500/kW, down from $1,200/kW in 2020. The value pool here concentrates in integrated manufacturing: companies that control stack production, balance-of-plant engineering, and commissioning capture 25-35% gross margins versus 10-15% for component-only suppliers.

Industrial cluster demand aggregation

The most bankable hydrogen projects are those co-located with multiple offtakers in industrial clusters. The Humber Industrial Cluster in the UK aggregates demand from BP, British Steel, and Equinor across refining, steelmaking, and power generation, targeting 1 GW of blue hydrogen production by 2027. HyNet North West connects hydrogen production at Stanlow refinery to glass manufacturing, chemicals, and heating demand across Liverpool and Manchester. In Germany, the GET H2 Nucleus project links Lingen green hydrogen production (100 MW electrolyzer) to BP's refinery and multiple chemical plants via a 130 km repurposed pipeline. Cluster economics work because shared infrastructure (pipelines, storage caverns, port facilities) reduces per-unit transport costs by 40-60% compared to point-to-point delivery.

E-fuel offtake commitments in aviation

Sustainable aviation fuel (SAF) mandates are creating the most visible near-term e-fuel value pool. The EU ReFuelEU Aviation regulation requires 1.2% synthetic SAF by 2030 and 35% by 2050. This translates to roughly 600,000 tonnes of e-kerosene demand by 2030 in Europe alone. HIF Global's Haru Oni pilot plant in Chile has delivered the first commercial e-fuel batches to Porsche and is scaling to 550 million litres annual capacity by 2027. Infinium has contracted 42,000 barrels of annual e-fuel production for airlines including American Airlines and Amazon Air. The value concentrates in project developers who secure renewable electricity at <$30/MWh and CO₂ offtake simultaneously, as feedstock costs represent 60-70% of e-fuel production costs.

What's Not Working

Standalone green hydrogen production without offtake

Multiple high-profile green hydrogen projects have stalled or been cancelled due to missing offtake agreements. Fortescue Future Industries shelved its 2 GW Phoenix Hydrogen Hub in Arizona in 2024 after failing to secure industrial buyers at $4-5/kg. The Namibian government's planned 5 GW green hydrogen export project attracted 14 expressions of interest but zero binding offtake contracts. Without committed buyers willing to pay a green premium of $1.50-3.00/kg over grey hydrogen, project finance remains unavailable. The lesson is clear: production-first strategies that assume demand will follow have a failure rate exceeding 60% based on announced versus financed projects through 2025.

Hydrogen transport over long distances

Moving hydrogen economically remains the sector's largest unsolved challenge. Gaseous hydrogen pipelines cost $1.2-2.5 million per kilometre for new build, and liquefaction adds $1.50-2.50/kg in processing costs. Shipping liquid hydrogen requires cryogenic vessels operating at -253 degrees Celsius, with boil-off losses of 0.2-0.5% per day. Kawasaki Heavy Industries' Suiso Frontier demonstration delivered 75 tonnes of liquefied hydrogen from Australia to Japan in 2022 at an estimated landed cost exceeding $15/kg. Ammonia conversion for transport adds $0.80-1.20/kg in cracking and reconversion losses. These economics explain why the value pool in hydrogen favours local or regional production-consumption models over intercontinental trade for all but the highest-value applications.

Electrolyzer utilization rates

Many announced projects assume electrolyzer utilization rates of 80-90%, but real-world performance tells a different story. Dedicated renewable-powered electrolyzers in northern Europe average 35-45% capacity factors due to wind and solar intermittency. Adding battery storage to smooth output raises capital costs by 30-50%. Grid-connected electrolyzers achieve higher utilization but face challenges meeting "additionality" requirements under EU delegated acts, which require temporal and geographic correlation with renewable generation. Low utilization directly inflates LCOH: a 40% capacity factor produces hydrogen at roughly double the cost of an 80% factor from the same equipment.

Key Players

Established Leaders

• Air Liquide: World's largest industrial gas company, operating 50+ hydrogen production facilities globally. Invested EUR 8 billion in low-carbon hydrogen through 2035.
• Linde: Major hydrogen producer with 200+ production plants and the world's largest liquid hydrogen capacity. Supplies 80+ hydrogen fueling stations in Europe.
• Shell: Operating Holland Hydrogen I, Europe's largest green hydrogen plant (200 MW), with plans for 10+ GW of electrolyzer capacity by 2030.
• BP: Leading the HyGreen Teesside project (80 MW initially scaling to 500 MW) and developing integrated hydrogen hubs across the UK and Germany.

Emerging Startups

• Electric Hydrogen: Raised $380 million to manufacture 100 MW PEM electrolyzer modules at scale in the US. Targets industrial customers needing on-site hydrogen at below $2/kg.
• Hysata: Australian startup developing capillary-fed electrolyzers achieving 95% system efficiency (versus 70-75% for conventional systems). Raised $111 million Series B.
• Infinium: Produces ultra-low carbon e-fuels from green hydrogen and captured CO₂. Secured contracts with Amazon, American Airlines, and multiple European carriers.
• HIF Global: Developing the world's first commercial-scale e-fuels plant in Chile (Haru Oni) with backing from Porsche and ExxonMobil.

Key Investors and Funders

• Breakthrough Energy Ventures: Bill Gates-backed fund with $2 billion deployed across hydrogen and e-fuel startups including Electric Hydrogen and Form Energy.
• Hy24: Joint venture between Ardian and FiveT Hydrogen managing the world's largest clean hydrogen fund at EUR 2 billion.
• UK Net Zero Hydrogen Fund: GBP 240 million government fund supporting hydrogen production projects through CAPEX grants and revenue support.

Action Checklist

1. Map your organisation's hard-to-abate energy demand (high-temperature heat, heavy transport, chemical feedstock) to identify where hydrogen displaces fossil fuels most cost-effectively.
2. Evaluate proximity to industrial clusters with shared hydrogen infrastructure plans, as co-location reduces delivered cost by 40-60%.
3. Secure binding offtake agreements before committing capital to production assets, targeting 10-15 year terms with price indexation to carbon markets or electricity costs.
4. Assess electrolyzer technology choices based on application requirements: alkaline for steady-state baseload, PEM for dynamic operation paired with variable renewables.
5. Model total delivered cost including transport, storage, and conversion losses rather than production cost alone, as midstream costs can double the final hydrogen price.
6. Track policy developments including EU delegated acts on renewable hydrogen definitions, US 45V production tax credit guidance, and UK low-carbon hydrogen certification.
7. Consider ammonia or methanol as hydrogen carriers for applications where reconversion losses are acceptable and liquid logistics are advantageous.

FAQ

Where are the largest hydrogen value pools through 2030? The three highest-value pools are electrolyzer manufacturing (projected $35 billion market by 2030), industrial cluster infrastructure development (pipelines, storage, and distribution representing $50-80 billion of investment), and e-fuel production for aviation and shipping (reaching $25 billion by 2030 on mandated demand alone). Margins are highest in integrated project development and midstream infrastructure rather than commodity hydrogen production.

How does blue hydrogen compete with green hydrogen on cost? Blue hydrogen currently costs $1.50-3.00/kg versus $3.50-6.00/kg for green. However, the gap is closing at 15-20% per year as electrolyzer costs decline and renewable electricity prices fall. By 2028-2030, green hydrogen is expected to reach cost parity with blue in regions with strong solar or wind resources. Blue hydrogen faces additional risk from methane leakage scrutiny and CCS storage liability.

Which regions offer the best economics for green hydrogen production? Chile, Australia, the Middle East, and North Africa offer the lowest production costs due to high-quality solar resources achieving capacity factors above 25%. The US Gulf Coast combines strong wind and solar with existing pipeline infrastructure and IRA subsidies of up to $3/kg. Northern Europe has higher production costs but benefits from proximity to industrial demand and established gas grid infrastructure suitable for repurposing.

What role do e-fuels play versus direct hydrogen use? E-fuels make economic sense where drop-in compatibility with existing infrastructure outweighs the 30-40% energy conversion penalty. Aviation is the clearest case: jet engines cannot burn hydrogen directly, and battery-electric flight is limited to short ranges. Shipping is split between direct ammonia combustion and e-methanol depending on vessel type and route. For industrial heat and ground transport, direct hydrogen or electrification typically offers better economics than e-fuel conversion.

Sources

1. International Energy Agency. "Global Hydrogen Review 2025." IEA, 2025.
2. Hydrogen Council and McKinsey. "Hydrogen Insights 2025: An Updated Perspective on Hydrogen Market Development." Hydrogen Council, 2025.
3. European Commission. "REPowerEU: Hydrogen Accelerator Implementation Report." EC, 2025.
4. BloombergNEF. "Hydrogen Economy Outlook: Electrolyzer Market and Cost Trajectories." BNEF, 2025.
5. UK Department for Energy Security and Net Zero. "UK Hydrogen Strategy: Progress Update 2025." DESNZ, 2025.
6. International Renewable Energy Agency. "Green Hydrogen Cost Reduction: Scaling Up Electrolysers to Meet the 1.5C Climate Goal." IRENA, 2024.
7. Transport & Environment. "E-fuels for Aviation: Cost Projections and Mandate Compliance Pathways." T&E, 2025.