Report Highlights

Who Controls This Market — And Who Is Threatening That Control

No company controls the offshore green hydrogen market — the category has no commercial-scale production facility in operation globally as of 2025. The market is defined by announced projects and development-stage investments rather than operational assets. Ørsted, the world's largest offshore wind developer, has the most credible pathway to offshore green hydrogen through its existing offshore wind development capabilities, port infrastructure relationships, and the organisational knowledge to integrate electrolysis with variable offshore wind power generation. Its NortH2 project in the Netherlands (targeting 4 GW electrolyser capacity by 2030, powered by 10 GW of North Sea offshore wind) is the most ambitious single offshore green hydrogen project globally. Shell's Holland Hydrogen I (200 MW electrolyser, Maasvlakte Rotterdam, operational 2023) and its North Sea offshore wind-to-hydrogen projects represent the most advanced large-oil-company commitment to the offshore hydrogen transition.

The competitive dynamics in offshore green hydrogen differ fundamentally from most energy markets. The incumbents are not fossil fuel incumbents defending existing positions but emerging players competing to establish first-mover advantages in project development, electrolyser supply chain, and industrial buyer relationships before the market reaches commercial scale. ITM Power and Nel Hydrogen are the leading electrolyser manufacturers competing for the multi-gigawatt electrolyser contracts that offshore hydrogen projects require, with cost reduction from scale manufacturing being the primary competitive variable that determines project economics across the entire sector.

Industry Snapshot

Offshore green hydrogen uses electrical power from offshore wind turbines to split water into hydrogen and oxygen through electrolysis. The offshore production pathway offers two approaches: onshore coastal electrolysis powered by offshore wind via subsea cables (the majority of near-term projects), and fully offshore electrolysis on dedicated platforms positioned near offshore wind farms with hydrogen transported to shore by pipeline or as ammonia/liquid organic hydrogen carriers. The onshore coastal approach benefits from lower electrolyser maintenance costs and existing infrastructure but requires subsea cable installation and energy transmission losses. Fully offshore electrolysis eliminates cable costs and transmission losses for high-capacity distant offshore wind sites but introduces marine engineering challenges for electrolyser maintenance, water purification at sea, and hydrogen compression and export. Both approaches face the fundamental challenge that green hydrogen production economics are highly sensitive to electrolyser capacity factor — a 40% capacity factor for offshore wind means electrolysers are idle 60% of the time, requiring capital cost amortisation over lower production hours than onshore electrolysers paired with solar or mixed renewable grids.

The Forces Accelerating Demand Right Now

EU hydrogen policy is the primary demand driver for European offshore green hydrogen. The EU's REPowerEU plan targets 10 million tonnes of domestic green hydrogen production and 10 million tonnes of green hydrogen imports annually by 2030, with the Hydrogen Bank auction mechanism providing EUR 800 million in direct subsidies to green hydrogen projects in the first auction round. The European Hydrogen Backbone pipeline network — 28,000 km of new and repurposed natural gas pipelines targeted for hydrogen transport by 2030 — is building the infrastructure for offshore hydrogen from North Sea, Baltic, and Atlantic wind resources to reach industrial demand centres in Germany, Belgium, the Netherlands, and France. Industrial decarbonisation demand from steel (ArcelorMittal, ThyssenKrupp, SSAB), ammonia (Yara, BASF, Fertiberia), and refinery sectors is creating long-term offtake commitments that provide the revenue certainty needed for offshore hydrogen project financing at scale.

What Is Holding This Market Back

Project economics remain challenging — offshore green hydrogen produced in 2025 costs USD 5–9/kg, versus USD 1–2/kg for grey hydrogen from natural gas steam methane reforming. The electrolyser capital cost (USD 800–1,200/kW for PEM electrolysers at current scale), offshore wind integration engineering costs, and hydrogen compression and export infrastructure collectively require green hydrogen pricing of USD 3–5/kg to achieve competitive project returns — a price that industrial buyers are unwilling to pay without government support. Electrolyser supply chain constraints — limited annual manufacturing capacity for large-scale electrolyser stacks, critical material dependencies on iridium and platinum for PEM electrolysers — create lead time and cost risks for multi-gigawatt project procurement. The regulatory framework for offshore hydrogen pipelines, platform safety, and maritime jurisdiction for electrolysis facilities is still being developed in most North Sea jurisdictions, creating approval uncertainty that delays project FID (Final Investment Decision).

The Investment Case: Bull, Bear, and What Decides It

The bull case projects green hydrogen reaching cost parity with grey hydrogen (USD 1.5–2.0/kg) by 2032–2035 through electrolyser learning curves (60%–70% cost reduction per doubling of cumulative installed capacity is the industry benchmark), renewable energy cost reduction, and scale manufacturing efficiencies. At cost parity, the addressable market for green hydrogen — replacing grey hydrogen in ammonia synthesis (170 million tonnes annually), refinery operations, and steel production — represents USD 150–200 billion in annual feedstock demand. Offshore wind-powered green hydrogen has a geographic reach advantage over solar-based onshore green hydrogen for European industrial demand, justifying the higher production cost relative to desert solar sites in Spain or North Africa.

The bear case observes that green hydrogen cost reduction projections have been consistently optimistic — electrolyser learning curves have not yet matched solar PV or battery cost reduction rates, and the offshore engineering premium for hydrogen production is not subject to the same mass manufacturing learning curve as electrolyser hardware. Blue hydrogen (from natural gas with carbon capture) offers industrial decarbonisation at USD 1.5–2.5/kg by 2030, potentially capturing the industrial transition market before green hydrogen achieves competitive cost. The decisive variable is whether PEM electrolyser manufacturing scale-up achieves the cost reduction trajectory projected by Siemens Energy, Nel, and ITM Power in their 2026–2030 manufacturing expansion programmes.

Where the Next USD Billion Is Being Built

Ammonia as a hydrogen carrier is the most commercially actionable offshore green hydrogen pathway — green ammonia synthesised at coastal facilities from offshore wind hydrogen can be shipped globally using existing liquid ammonia tanker infrastructure, accessing industrial demand in Japan, South Korea, and China that cannot be served by pipelines. The green ammonia market for agricultural fertiliser replacement and marine fuel is a USD 5–10 billion near-term opportunity for projects combining offshore wind, electrolysis, and Haber-Bosch ammonia synthesis at coastal export terminals. Electrolyser stack manufacturing — the capital equipment and materials supply chain supporting multi-gigawatt offshore hydrogen projects — is a USD 3–8 billion opportunity for scale manufacturing investors willing to commit capital ahead of confirmed project pipelines.

Market at a Glance

Regional Intelligence

North-West Europe — the North Sea basin covering UK, Norwegian, Dutch, Belgian, and Danish waters — is the epicentre of offshore green hydrogen development, with the combination of Europe's strongest offshore wind resource, existing offshore energy infrastructure, industrial hydrogen demand in Rotterdam and the Ruhr Valley, and EU hydrogen policy support creating the most favourable geography for offshore green hydrogen project development globally. The UK has announced USD 2 billion in green hydrogen support through its Hydrogen Allocation Round mechanism, with offshore wind-to-hydrogen projects eligible for long-term contract-for-difference revenue support. Norway's combination of offshore wind resources, existing natural gas pipeline infrastructure (potentially repurposed for hydrogen), and sovereign wealth fund investment capacity positions it as a potential green hydrogen export hub for European industrial demand. East Asia — Japan, South Korea, and Australia — is the second major offshore green hydrogen development geography, with Japan's Green Innovation Fund and South Korea's Hydrogen Economy Roadmap providing government support for offshore hydrogen development targeting industrial decarbonisation of these import-dependent economies.

Leading Market Participants

• Shell
• Equinor
• Siemens Energy
• Nel Hydrogen
• RWE

Long-Term Market Perspective

By 2034, offshore green hydrogen will have reached commercial production at scale in North-West Europe and East Asia, with cumulative installed offshore wind-powered electrolysis capacity of approximately 5–10 GW globally — far below the 100 GW that 2030-era projections assumed, but sufficient to demonstrate commercial viability and support the next investment cycle. The market structure will bifurcate between coastal onshore electrolysis (the majority of production) and fully offshore platforms (a smaller premium segment for high-capacity distant offshore wind sites). Green ammonia export will define the intercontinental offshore hydrogen trade, with Australia, Norway, and Chile emerging as the primary export hubs and Japan, Germany, and South Korea as the primary importers.