The IEA’s 2025 review says low-emissions hydrogen remained below 1% of global production. It identifies high costs, uncertain demand and infrastructure delays as barriers. The potential 2030 output represented by announced projects fell from 49 to 37 million tonnes per year between the 2024 and 2025 reviews, following delays and cancellations.
Source: IEA: Global Hydrogen Review 2025.
Compare products on a consistent basis
Our editorial interpretation is that “grid parity” obscures the actual comparison: hydrogen is a fuel and industrial input, while grid electricity is a different product. A meaningful assessment specifies production method, emissions boundary, delivery location and customer use. An announced electrolyser is not evidence that affordable hydrogen has been delivered to a buyer.
Practical checks
- Separate announcements, final investment decisions, construction and operation.
- Identify whether a figure concerns renewable hydrogen or a broader low-emissions category.
- Compare delivered costs for the same use and location.
- Treat 2030 output as a projection with assumptions.
- Seek operating evidence before claiming a market-wide cost breakthrough.
Engineering, economics and evidence
Conventional hydrogen still dominates
The International Energy Agency's September 2025 Global Hydrogen Review reported that worldwide hydrogen demand approached 100 million tonnes in 2024. Most of this demand came from established industrial uses such as refining and chemical production, and supply remained dominated by fossil-fuel-based processes. Low-emissions hydrogen accounted for less than one percent of total production. Those figures help put new project announcements in perspective. A growing number of proposed renewable-energy projects does not mean the global hydrogen system has already switched to clean production. Market share and annual output are separate from a developer's ambition.
Low emissions is a category, not one production method
The IEA uses the term low-emissions hydrogen for pathways that meet specified emissions criteria, including hydrogen made through electrolysis and certain fossil-based pathways with carbon capture. Renewable hydrogen is a narrower category tied to the origin of the electricity used for electrolysis. Reporting should not treat every low-emissions project as powered exclusively by solar or wind energy. The environmental outcome depends on the actual energy supply, process emissions, capture performance and measurement boundaries. Project descriptions must name their technology and evidence rather than assume the word hydrogen is inherently a climate benefit.
Announced output fell after cancellations
The IEA's 2025 review revised the potential production represented by announced low-emissions projects for 2030 to approximately 37 million tonnes a year, down from 49 million tonnes in the preceding edition. The reduction reflected delays and project cancellations. That is not the same as a 12-million-tonne fall in hydrogen already being produced. It is a change in the prospective project pipeline. The distinction is central: investors can announce a facility that later fails to secure financing, permits or buyers. Forecasts should be labeled as forecasts and compared with the same report's underlying assumptions.
Final investment decisions offer stronger evidence
More than 200 low-emissions hydrogen production projects had reached final investment decision since 2020, according to the IEA's 2025 assessment, while many others remained at earlier stages. FID indicates a greater level of financial commitment than a proposal, but it does not mean construction and operation are complete. The report estimated around 4.2 million tonnes per year of production by 2030 from projects already operating or at FID, a much smaller figure than the overall announced pipeline. Reporting should place the realistic committed capacity alongside the ambitious total instead of presenting the latter as guaranteed supply.
Cost is a delivered product question
Hydrogen produced by electrolysis depends on electricity prices, equipment cost, utilization and financing. Fossil-based hydrogen has different inputs, while capture-equipped production adds its own infrastructure and storage expenses. The IEA says the cost gap between low-emissions and unabated fossil-based supply remains an obstacle, with prospects varying across countries. A slogan such as hydrogen reaching grid parity is especially misleading because grid electricity and hydrogen are different products. A valid comparison identifies a specific end use, delivered hydrogen price, competing fuel, location and emissions requirement.
Electrolyser prices vary by region
The IEA's 2025 review describes large differences between electrolyser installation costs in China and other regions, while explaining that transport, tariffs, engineering and local standards can narrow the gap when equipment is imported. An inexpensive factory price does not establish the installed cost or operating efficiency of a complete plant. Maintenance, project financing and integration with power supplies also matter. Buyers should ask for quotations covering all project stages rather than multiply a bare equipment price by planned capacity. A market headline based on factory costs alone can exaggerate how close hydrogen is to commercial competitiveness.
Demand uncertainty can stop investment
A producer needs customers willing to buy hydrogen under terms that cover production and delivery costs. The IEA highlights limited firm offtake agreements as a major reason projects struggle to secure finance. A memorandum of understanding or nonbinding interest statement is not equivalent to a contracted purchase volume. Industrial users also need confidence that low-emissions hydrogen will be available at the required quality and reliability. Policymakers discussing investment should consider demand creation alongside production incentives, because a plant without a viable customer can become an expensive stranded asset.
Infrastructure is not optional
Hydrogen requires appropriate storage, transport, handling and safety systems. A production plant near a port or industrial customer can have different costs from a remote facility intending to export to another continent. Moving hydrogen directly or converting it into derivatives such as ammonia creates further engineering and energy requirements. The IEA discusses industrial clusters and ports as possible early opportunities because infrastructure and demand may be concentrated there. The presence of a renewable energy resource alone does not make an export project bankable. Delivery logistics are part of the product cost.
Near-term applications remain concentrated
The IEA notes that existing industrial uses such as refining, chemicals and fertilizer can offer relatively direct opportunities to replace conventional hydrogen with lower-emissions alternatives. Emerging uses in shipping, steel or aviation may require new equipment, standards and fuel supply networks. A project announcement for a new market does not prove that customers will quickly convert their processes. Demand should be evaluated by sector and facility, with clear evidence for offtake and regulatory requirements. A claim that hydrogen will soon power every part of the economy exceeds the demonstrated breadth of adoption.
Measure production and emissions after commissioning
A credible project evaluation tracks actual kilograms or tonnes produced, energy consumed, emissions intensity, delivery costs and customer use over a defined period. Financial announcements and electrolyser nameplate capacity are useful indicators of future potential but not proof of sustained output. The IEA's 2025 review documents meaningful progress alongside persistent problems of cost, demand and infrastructure. Updated data may change the outlook as projects proceed or are cancelled. The supported conclusion is that a young low-emissions segment is expanding from a small base, not that broad price parity or a completed energy transition has been achieved.
Primary source: Official technical or energy report.
