China's hydrogen turning point is a pipeline problem, not a technology one
China dominates electrolyser manufacturing and holds the largest hydrogen consumption in the world. Green hydrogen is still under 1% of it. What stands between the two is less than 500 km of pipeline.
China is routinely described as the world leader in hydrogen, and on manufacturing capacity that is accurate. The IEA's Global Hydrogen Review 2025 puts China at 65% of global installed electrolyser capacity and nearly 60% of global electrolyser manufacturing capacity.
The domestic picture is less flattering, and considerably more useful to anyone deciding where to place a bet.
The structural reality behind the headline
China consumes roughly 39 million tonnes of hydrogen a year — the largest volume in the world. Over 60% comes from coal gasification. Industrial by-product hydrogen accounts for more than 30%. Genuinely green hydrogen is under 1%.
Green hydrogen output did exceed 250,000 tonnes a year in 2025, ahead of the 100,000–200,000 tonne target set in the Medium- and Long-Term Plan for the Development of the Hydrogen Energy Industry (2021–2035), released by the National Development and Reform Commission and the National Energy Administration in March 2022. Beating the target is real. It is also less than one per cent of national consumption.
The plan runs in three stages: an initial supply chain and roughly 50,000 fuel cell vehicles by 2025; a relatively complete innovation and clean hydrogen supply system by 2030; a diversified application ecosystem across transport, storage and industry by 2035. As of early 2026 the country is in the climb from the first stage to the second.
The turning point has not arrived. It is worth being precise about what would have to happen for it to.
Where the demand actually gets built
Decarbonisation is running down three routes, and they are not equally mature.
Chemicals — green hydrogen into green ammonia and methanol. This is the path with the most immediate scale. The State Power Investment Corporation project at Da'an in Jilin runs 32,000 tonnes of green hydrogen into 180,000 tonnes of green ammonia annually. China Energy Engineering Corporation's Songyuan project pairs 800,000 kW of new energy with 200,000 tonnes of green ammonia, its synthesis unit running at 80% capacity and producing over 500 tonnes a day. Forty-one projects sit in the first national batch of hydrogen pilots, and a first tranche of 1.48 million tonnes a year of green liquid fuel capacity has been laid out.
Steel — hydrogen metallurgy moving from pilot to commercial. The hardest route and the most consequential. Ansteel's Bayuquan fluidised-bed hydrogen ironmaking line was completed in April 2026 with a 95% metallisation rate. The Baotou integrated green electricity, hydrogen and steel project, signed in December 2025 with phase one launched in April 2026, replaces coke reduction and cuts carbon emissions by over 90%. Guidance from five ministries on zero-carbon factory construction lists hydrogen alongside zero-carbon electricity and heat for the first time, targeting expansion into steel, non-ferrous metals and petrochemicals by 2030.
Refining and coal chemicals — blending and substitution. Gradual, and constrained by the thing that constrains everything: green hydrogen runs around CNY 25/kg against CNY 8–12/kg for grey.
The bottleneck is geography
Roughly 90% of green hydrogen is produced in the three northern regions. Demand sits on the eastern seaboard.
China's dedicated hydrogen pipeline network totals less than 500 km, against over 4,500 km in Europe and the United States. The economic radius of a long-tube trailer is about 200 km. Transport accounts for close to 40% of total supply cost.
That is the whole problem in three numbers. The electrolysers exist, the projects exist, the policy exists — and the molecules cannot get to the customers economically.
Some of the institutional groundwork is being laid. A notice in early 2026 on orderly promotion of direct green power connection allows dedicated renewable lines to supply hydrogen production directly, addressing traceability and price. An off-grid 25 MW wind-to-hydrogen project in Tieling, Liaoning was selected as a national pilot, proving curtailed wind can become hydrogen rather than nothing. In the wind- and solar-rich north, hydrogen is the only viable large-scale seasonal storage medium — batteries are too expensive for a job measured in weeks.
Large but not strong
China holds over 60% of global electrolyser capacity and around 70% of fuel cell system capacity. The manufacturing base is not in question. Its quality is.
- Alkaline electrolysers — 90% of products share the same design blueprints, producing brutal price competition. Load regulation of only 20–100% makes pairing with wind and solar awkward.
- PEM electrolysers — fast dynamic response, but membrane lifespans of 3,000–5,000 hours, with perfluorosulfonic acid membranes and iridium catalysts still imported.
- AEM — the emerging research focus, with the first wide-width product now unveiled.
- SOEC — high-temperature electrolysis, still experimental. A long-term reserve.
- Fuel cell vehicles — domestic production of core components sits below 30%, with pressure sensor chips among the imports.
Cumulative hydrogen patent applications passed 100,000 by the end of 2025, first in the world. Of 59 key technologies, six are assessed as leading and 13 as level with international peers. But the industry's own view is that the preference for cheap alkaline units has squeezed the margins that fund innovation, and the genuine chokepoints — proton exchange membranes, catalysts, sensor chips — remain unsolved.
That is the difference between the largest manufacturer and the strongest one.
The unglamorous part: standards and legal status
The most underrated element of the strategy is institutional.
130 national hydrogen standards have been released, with 19 more under public comment as of February 2026. Forty-six industry standards are out; 18 more covering green hydrogen production, pipelines and storage were approved in 2024. Add roughly 50 local and 500 group standards. In January 2026 the National Energy Administration created seven new standardisation bodies, four of them for hydrogen — basic and general, production, storage and transport, application. That is a shift from fragmentation to specialised division of labour.
More consequential still: the 2024 Energy Law brought hydrogen into the national energy system for the first time, separating it from its status as purely a hazardous chemical. That reclassification is what makes hydrogen manageable as an energy medium rather than a controlled substance, and it is the precondition for everything else.
Safety remains genuinely unresolved. Over roughly twenty years, the fatality rate of hydrogen incidents runs at twice that of natural gas, with pipeline and valve failures accounting for 35.7%. Regulatory standards are not yet uniform across regions.
What has to converge by 2030
The 2030 inflection will not happen automatically. It requires several curves meeting:
- Economics — green hydrogen cost approaching grey plus a carbon price, helped by the CCER methodology released jointly by the Ministry of Ecology and Environment and the National Energy Administration, and continued falls in wind and solar LCOE.
- Infrastructure — inter-provincial pipelines connecting, so northern hydrogen reaches the east.
- Mandatory constraints — steel, chemicals and shipping facing binding emission timelines, so grey hydrogen loses its compliance space.
- Scale — marginal costs falling once green ammonia and methanol pass several million tonnes a year.
The China Electricity Council projects green hydrogen demand of 2.4–4.3 million tonnes a year by 2030, green ammonia and methanol output above 50 million tonnes, and total industry chain output value over CNY 1 trillion. Fossil-based hydrogen production is expected to peak around 2030.
A three-department pilot programme launched in 2026 selects city clusters on a challenge basis, aiming to bring end-use hydrogen below CNY 25/kg by 2030 and to CNY 15/kg in favourable regions.
What this means if you are on the European side
The equipment opportunity is not where the headline suggests. China's electrolyser industry is large, cheap and internally competitive to the point of self-harm. The gaps are specific and material: membranes, iridium catalysts, sensor chips, high-cycle-life stacks. That is a components conversation, not a machines conversation.
Watch the pipeline build, not the capacity announcements. Installed electrolyser capacity has repeatedly beaten targets. It has not moved the share of green hydrogen in consumption, because the transport economics do not work. Inter-provincial pipeline commitments are the leading indicator worth tracking.
Standards participation is a live opening. China is leading revision of international standards for compressed hydrogen fuel cell vehicle test methods and pushing green hydrogen certification toward international alignment. Certification alignment is where European bodies have real leverage and where decisions made now will shape market access later.
The official summary is unusually candid: green hydrogen is still small in scale, supply and demand are badly mismatched, homogenisation is serious, and safety supervision needs improvement. Take that at face value. It is a more reliable guide than the capacity figures.