China’s renewable hydrogen production capacity, now exceeding 1.4 million tonnes annually between what is operating and what is under construction, reads as validation that the production question is largely solved and attention can shift to storage, transport and demand.
Set against China’s total hydrogen production and consumption of roughly 35 million tonnes a year, more than 97% of it is still grey hydrogen from coal and natural gas; that entire renewable pipeline, even fully built out, would cover under 4% of the country’s hydrogen use. The operating share today is smaller still, at roughly 250,000 to 270,000 tonnes, under 1% of national hydrogen output.
The gap between what China has built and what is merely underway has also been widening, not narrowing. National Energy Administration data tracked across releases through 2026 shows operational renewable hydrogen capacity more than doubled between the end of 2024 and March 2026, from roughly 120,000 to 250,000 tonnes, but the construction pipeline grew faster still, reaching more than 900,000 tonnes under construction by March against that 250,000-tonne operational base, a ratio of well over three to one that held at similar proportions through the June figures showing 270,000 tonnes operational against 1.13 million under construction.
The argument that hydrogen infrastructure, storage and transport are now lagging behind production capacity is sound, but China’s own data shows a prior-stage problem still sitting underneath it: production capacity itself remains mostly unrealized, with the large majority of what gets counted toward the 1.4 million tonne headline figure not yet delivering a single kilogram of hydrogen.
The geographic concentration of what has actually been built offers a precise, data-backed version of the locational argument for combining renewable resources, infrastructure and industrial demand. Northeast China accounts for 45.7% of the country’s operational green hydrogen capacity from water electrolysis, with North China contributing 30% and the Northwest 21.8%, leaving every other region in the country combined at roughly 2.5%. Two provinces alone, Jilin, with more than 90,000 tonnes of operational capacity, and Inner Mongolia, with more than 80,000, account for a large share of the national total, both benefiting from strong wind resources that make electrolysis genuinely cost-competitive there.
That concentration validates the underlying claim that resource quality has driven where capacity actually gets built, but it also sharpens the infrastructure question rather than resolving it: China’s major steelmaking, chemical and port complexes sit predominantly in coastal and central provinces well outside the Northeast, Northwest and North China regions where this operational capacity has concentrated, meaning the industrial demand the broader argument says should complete the picture is largely not co-located with the renewable capacity that already exists.
Underground hydrogen storage, the technology Daye’s pilot project is meant to test, is also not the novel frontier the framing around it suggests globally, even if China’s specific approach is comparatively new. The United States, United Kingdom and Germany have earlier research and more extensive practical experience with salt cavern hydrogen storage specifically, and China’s own broader underground storage development has been, by the assessment of academic researchers in the field, relatively late by comparison.
What Daye is pursuing, rock cavern storage adapted from former mining infrastructure, is a more specific and considerably less proven variant than salt cavern storage, and it follows a smaller precedent already operating in China: Sinopec has run a hydrogen storage well in Chongqing since August 2021, storing hydrogen roughly 150 meters underground to supply 100 kilograms of hydrogen daily to a refueling station, a real but modest demonstration of underground storage at a scale many orders of magnitude below what large-scale rock cavern storage would eventually need to reach.
Daye’s own disclosed production scale is similarly modest relative to where China’s broader project pipeline has already moved. The Jiangqiao facility’s target of roughly 1,800 tonnes of annual green hydrogen production sits well below the 50,000-tonne-and-larger individual projects the National Energy Administration says are now breaking ground in Jilin and Inner Mongolia, and the project’s total disclosed investment of approximately 3.437 billion yuan, close to 480 million dollars, covers both that production facility and the underground storage research pilot combined.
That is a research and demonstration-scale commitment, consistent with a genuine pilot project testing whether former mining infrastructure can support hydrogen storage, but a considerably smaller undertaking than the “Mining to Underground Space to Energy Storage to Industrial Decarbonization” framing suggests is already operating at meaningful scale.
The broader thesis, that hydrogen competition is shifting from equipment to systems and from production cost to delivered cost, holds up against China’s own most recent data. What that data also shows is a systems-level challenge sitting on top of a production base still small relative to the country’s total hydrogen economy, concentrated in provinces geographically distant from major industrial demand, and only beginning, through pilots at the scale Daye represents, to test storage technology other countries have already spent longer developing.
