Hydrogen energy has moved from being a topic of academic or policy interest to being one of the central pillars in the global discussion of clean energy transitions. As nations commit to net zero goals and as industries look for ways to reduce carbon emissions in difficult sectors there is renewed attention on hydrogen. In this article I present a detailed view of where hydrogen energy is likely to go between now and 2040. I examine types of hydrogen production and cost trajectories; demand by sector; trade and infrastructure; policy forces; plausible scenarios; risks and uncertainties; regional differences; and investment implications. I emphasize the assumptions behind the projections so that the reader can assess the strength of the outlook.
Understanding Hydrogen Types and Roles
To speak clearly about hydrogen energy it is necessary to define what kind of hydrogen is meant and in what roles it plays. There are several categories of hydrogen by production method and by emission intensity. There is grey hydrogen which is produced from fossil fuels without any capture of the resulting carbon dioxide. There is blue hydrogen which uses fossil feeds plus carbon capture and storage methods in order to reduce the net emissions. There is green hydrogen which is produced by electrolyzing water using electricity generated by renewable sources. Green hydrogen has the lowest lifecycle emissions when the electricity is fully renewable and when the entire supply chain is clean.
Hydrogen is not a primary energy source. It is an energy carrier or vector. That means it requires energy input to produce. Its attractiveness depends on how that production is done and what emissions are involved. It also depends on cost and on what uses it enables that are difficult to electrify directly.
Roles for hydrogen include being a chemical feedstock; serving industrial heat demand; as a fuel for transport in segments where batteries are impractical; as a medium for seasonal storage of energy; as a contributor in power generation under certain conditions; or as a replacement or supplement in gas networks or for backup generation.
Production Capacity Cost Progress and Supply Pipeline
In recent years many announcements have appeared around planned production capacity for low emission hydrogen. Electrolyser manufacturers are expanding, renewable energy capacity is growing, and pipelines of hydrogen projects have become large on paper. Nevertheless many projects are delayed or scaled back. From reliable data sources the actual delivered supply is likely to fall short of many targets unless execution improves substantially.
Cost progress is underway. Renewable electricity costs continue to decline in many regions. Manufacturing costs for electrolysers, especially for key components such as stacks and membranes, are decreasing with scale and learning curves. Balance of plant costs including installation, power conditioning and water supply are also coming under pressure to fall. Clean hydrogen production costs are falling but are still higher than fossil based hydrogen in most existing markets if emissions costs or carbon penalties are low or absent.
In many regions the levelized cost of hydrogen from electrolysis when powered by excess or very low cost renewables may approach competitive levels by early to mid 2030s for industrial feedstock uses. But widespread competitiveness for transport use or for bulk energy storage will require further cost decline for electrolysers, cheaper renewable electricity, lower cost of hydrogen compression storage and transport.
At the same time blue hydrogen production depends heavily on effectiveness of carbon capture and storage. The capture rate must be high and leakage minimal for emissions reductions to be meaningful. The availability of geological storage plays a key role; in some regions there is sufficient suitable geological storage; in others there is little or none.
Demand Growth by Sector
Not all sectors will adopt hydrogen at the same speed or with the same scale. Some sectors are far more promising early adopters. Others may never use hydrogen broadly if alternatives are better.
Industrial and Chemical Feedstocks
Industry is likely to be the first and largest domain of hydrogen demand growth. Production of ammonia for fertilizers already uses hydrogen heavily. Steelmaking especially via direct reduction of iron using hydrogen offers a compelling route to decarbonize a sector that is very hard to decarbonize by other means. Refining processes need hydrogen. Chemical plants producing methanol or other basic chemicals can transition to low emission hydrogen to reduce their carbon footprint. In many cases industrial users can justify the investment because the plants are large and the hydrogen demand is steady. The cost premiums can be absorbed when regulated or when customers demand low carbon content in products.
Transport in Hard-to-Electrify Segments
Transport segments where electrification by battery is difficult are likely to adopt hydrogen or hydrogen derived fuels. Long haul trucking over large distances, heavy duty vehicles, maritime shipping, aviation fuel supply feedstocks are notable here. For example hydrogen derived synthetic fuels or ammonia may serve in marine bunkers or as aviation feedstocks where energy density and weight matter. Fuel cell vehicles may penetrate part of road transport where weights and refueling time permit. Pilot corridors linking hydrogen refueling stations may appear first in rich or densely populated regions.
Seasonal Energy Storage and Grid Balancing
One of hydrogen’s strongest roles is as a buffer or storage medium for times when renewable generation exceeds demand or for times when there is low renewable production over extended periods. Batteries are efficient for short term balancing but less efficient or more expensive for seasonal or multi-week storage. Hydrogen can store energy for months particularly when coupled with renewable overgeneration or curtailed electricity. Then when supply is low hydrogen may be used to generate electricity or feed industrial processes.
Power Generation and Heating
In power generation hydrogen may be used in some specific situations. For backup generation where reliability is essential; or for peak power plants where renewable supply is insufficient. For heating in buildings hydrogen can play a role especially in regions where retrofitting is difficult or where fuel infrastructure already exists. Gas grids may blend hydrogen to some percentage in existing pipelines. However full substitution of gas or full replacement of electric heating seems unlikely in most regions by 2040 unless hydrogen becomes very cheap and infrastructure investment moves quickly.
Trade Infrastructure and Geography
Hydrogen does not work without infrastructure. Transport, storage, pipelines, import and export terminals, ports fitted for modern fuels are all required. Geography and natural resource endowments matter greatly.
Regions with very large renewable energy potential and cheap land such as parts of Australia, South America, Middle East, North Africa may become exporters of hydrogen or hydrogen derivatives such as ammonia or synthetic fuels. Exporting requires reliable logistics: liquefaction or conversion to ammonia; shipping; regasification or cracking back into hydrogen; low carbon accounting so that the exported product is verifiably low emission.
Importing regions are likely to include Europe, parts of Asia and others where demand is large but domestic renewable potential is limited or more expensive. Those importing regions will invest in terminals, storage, pipelines and in regulations to ensure hydrogen quality and low carbon credentials.
The pipeline infrastructure for hydrogen or for hydrogen derived fuels must scale. Electrolyser manufacturing capacity must scale far beyond what existed in early 2020s. Supply chains for catalysts, membranes, electrolyser stacks, rare metals, and for materials resistant to hydrogen embrittlement in pipelines are all critical. Transportation (truck, rail, pipeline) cost and safety requirements matter.
Policy Forces and Targets
Many countries have announced hydrogen strategies. Public policy is a major driver of demand and of risk in this field. Governments offer subsidies, contracts for difference, tax credits, performance standards, emissions regulations, clean fuel mandates. Some policies set targets for green or low emission hydrogen production capacity by 2030 or 2035. Others offer financial support for infrastructure or for early offtake agreements to reduce investment risk.
Yet many announced targets are ambitious. Empirical evidence shows that many such goals may not be met on time due to permitting delays, supply chain issues, capital cost escalation, regulatory uncertainty. Policy continuity and stable incentives are essential. When policies flip or when carbon pricing is low or inconsistent then investor confidence suffers and projects stall.
Policies around transport fuel standards, industrial emissions mandates, carbon pricing or emissions trading, building codes for heating, gas grid blending all shape hydrogen demand. Another factor is international coordination for trade and standardization of hydrogen quality, measurement of lifecycle emissions, certification systems. Without clear standards leakage or double counting may undermine confidence.
Scenarios to 2040
Because of the many uncertainties I map three plausible scenarios through 2040. These scenarios allow comparison and help reveal which variables matter most.
Scenario One: Strong Acceleration
Assumptions in this scenario include aggressive policy support globally; high carbon pricing; major investment in renewables; very large electrolyser manufacturing scale up; robust international trade in hydrogen or its derivatives; breakthroughs in cost reductions in electrolysers and transport.
Under this scenario by the early 2030s green hydrogen costs in many favorable locations fall toward parity with fossil hydrogen. Industrial demand for hydrogen grows sharply especially in steel, chemical manufacturing, refining. Transport applications such as hydrogen fuel cell heavy vehicles, long haul trucking or hydrogen derived fuels for shipping begin to scale. Regions such as Europe and East Asia import hydrogen or ammonia from exporting regions. Seasonal storage of hydrogen for electricity generation in months of low renewable output becomes common in high renewable grid regions. By 2040 hydrogen becomes a major component of energy systems especially in difficult to decarbonize sectors. Global clean hydrogen production including green and blue types may reach many multiples of early 2020s levels.
Scenario Two: Gradual Growth
In this scenario policy support continues but is variable between countries. Electrolyser and renewable cost declines proceed steadily but not at full potential. Infrastructure scaling is uneven. Supply chain constraints slow some projects. Public investment is steady though risk premia remain significant in many markets.
Here hydrogen grows substantially in industrial and chemical sectors. Some transport uses take off but more slowly. Export and import trade emerges but in limited volumes. Seasonal or backup power use increases but remains secondary to other storage forms. Cost reductions make green hydrogen competitive for specific industrial feedstock uses in favorable geographies by mid 2030s. By 2040 hydrogen is widely accepted in niche areas and begins to enter more mainstream usage but not uniformly.
Scenario Three: Stalled or Limited Adoption
In this scenario many obstacles prolong the transition. Regulatory uncertainty or loosening of climate policy in major markets reduces incentives. Cost of key materials for electrolysers remains high. Renewable energy expansion is constrained by grid or land use. Storage, transport, infrastructure investment lags. Financing becomes harder. Competition from direct electrification, biofuels and efficiency measures reduces hydrogen’s potential surfaces of growth.
In this case hydrogen remains marginal beyond existing uses. Industrial feedstock demand may expand somewhat but slowly. Transport use remains limited to special cases. Trade remains limited and expensive. By 2040 hydrogen contributes only a small fraction of the energy used in heating or in power which remains heavily dependent on conventional fuels and electricity. Many targets announced earlier are missed or delayed by years.
Key Risks Uncertainties
Several factors could shift the path of hydrogen energy substantially. Understanding these helps in making investment or policy decisions.
- Cost Trajectories Uncertainty
If renewable electricity remains expensive or variable; if electrolyser manufacturing does not scale fast; if supply chains for rare or critical materials fail; then costs of green hydrogen remain high and adoption slows. - Carbon Capture and Storage Performance Risk
Blue hydrogen depends heavily on capture rates, on storage integrity, on regulation of fugitive emissions. If capture efficiency is low or if leakage is large then lifecycle emissions may be much higher than projected. - Infrastructure Bottlenecks
Pipelines, compression, storage, transmission, import terminals, ports and regulatory approvals all require time and capital. Delays in permitting or community resistance or land use restrictions can slow deployment. - Regulatory and Policy Uncertainty
Policy consistency over long periods is essential for investors. If policies are changed, if subsidies retract, if carbon pricing weakens, or if mandates are delayed then many projects become unviable. - Competition from Alternatives
Battery storage, advanced biofuels, synthetic fuels, direct electrification and energy efficiency improvements compete with hydrogen in many uses. If these alternatives improve faster than expected hydrogen may lose market opportunities. - Regional and Geographic Constraints
Not all regions have abundant renewable energy or geological storage for carbon capture. Some locations face land constraints, water scarcity or high costs of transmission or transport. These will limit hydrogen deployment in those areas. - Lifecycle Emissions Scrutiny
Buyers increasingly demand evidence of low carbon intensity. If hydrogen is produced with fossil fuels and low capture or from grids with high emissions then credibility suffers. Measurement, certification, transparency matter greatly.
Regional Perspectives
Hydrogen deployment will vary greatly by region. The energy resource base, industrial structure, policy environment, geography and infrastructure all matter.
Europe
Europe is ambitious in its hydrogen strategy. Many member states have announced targets for capacities of green or low emission hydrogen by 2030 and 2035. Import dependency in Europe makes trade critical. Europe is likely to invest heavily in terminals, pipelines and certification systems. Industries in steel, chemicals and refining will be among early adopters. Some transport corridors may adopt hydrogen fuel cell heavy vehicles and hydrogen derived fuels for shipping. Gradual build out of hydrogen infrastructure will likely be ongoing through the period. Costs for hydrogen in favorable spots will fall enough for competitive industrial use by mid 2030s.
East Asia
Countries like Japan South Korea and parts of China are investing heavily. Japan has strategic interest in hydrogen import routes and shipping. South Korea similarly. China is large in manufacturing capacity for electrolysers and in renewable energy build out. China might both be exporter and large domestic user especially in chemical and industrial heat applications. East Asia may furnish many of the major offtake markets.
North America
United States and Canada have renewable resource potential but also regulatory and financial complexity. Federal and state level policies matter a great deal. Infrastructure investment in hydrogen pipelines or transport remains limited in many areas though growing. Industrial clusters may serve as early adopters. Transport applications will be concentrated where state level incentives are strong. Costs in favorable regions may decline sufficiently for green hydrogen industrial uses by mid 2030s. Export potential exists but is less certain.
Australasia Middle East and South America
These regions have some of the best resource potential for solar wind and land. That gives advantage for producing green hydrogen and derivatives for export. Several projects are planned in Australia and parts of the Middle East. South America has high potential in some areas though financing and infrastructure are challenges. These regions may become major suppliers to international markets.
Emerging Markets
In Africa Southeast Asia South Asia Latin America hydrogen adoption will be more challenging. Infrastructure financing is more difficult. Regulatory frameworks are weaker in many places. Renewable energy build out is uneven. Many of these regions may adopt hydrogen more slowly, focusing first on industrial or chemical applications if they exist. Export dependence and international finance may play strong role in enabling hydrogen growth.
Investment and Business Implications
Taking into account all of the above the following are implications for businesses investors and governments.
For Industry
Industrial companies should begin laying foundation now by securing renewable power partnerships; assessing where hydrogen or low emission hydrogen may reduce their carbon footprint; investing in pilot projects; considering flexibility in plant upgrades so they can shift to hydrogen if and when costs fall; entering into offtake agreements early to reduce risk.
For Transport Companies
Transport firms should watch and participate in emerging hydrogen refueling infrastructure; examine heavy duty vehicle use cases in long haul trucking and shipping where hydrogen or hydrogen derivatives may make sense; consider hybrid or dual fuel options; monitor regulatory developments such as clean fuel standards or emissions zones that might favor hydrogen.
For Energy and Utility Operators
Utilities and operators of grids should anticipate demand growth for electricity for hydrogen production; plan for integration of large scale electrolysers; plan grid flexibility; invest in storage; coordinate with industrial clusters and transport corridors; consider certificates and tracking systems for low emission hydrogen.
For Policymakers
Policymakers should provide stable long term incentives; enact clean fuel mandates; enforce carbon pricing or emissions trading; support infrastructure deployment such as pipelines, import terminals and refueling networks; ensure standards for measurement and certification of hydrogen emissions; facilitate permitting and reduce regulatory bottlenecks; support innovation in electrolyser technology and materials.
For Investors
Investors should evaluate hydrogen projects with attention to execution risk; focus on those with secure power supply and clear offtake contracts; consider export oriented projects; assess upstream risk in supply chains especially for electrolyser components; diversify exposure because many projects may not succeed; monitor policy trends closely because hydrogen economics depend heavily on regulatory environment.
Signals to Watch Over Coming Years
To understand whether the hydrogen energy outlook is unfolding as expected the following signals are critical.
- Trajectory of realised levelized cost of hydrogen in green and blue categories in major sites. How fast do actual produced costs fall in comparison with forecasts.
- Numbers of electrolyser projects that reach commercial operations rather than being announced and then delayed or cancelled.
- Progress in renewable energy deployment specifically for hydrogen production. Regions where renewable generation expands fast and cost falls significantly are likely to host more hydrogen investment.
- Infrastructure construction such as hydrogen import or export terminals, pipelines, transport logistics; regulatory approvals for pipelines or hydrogen blending in gas grids.
- Policy stability including carbon pricing, clean fuel mandates, subsidy schemes, low emission hydrogen certification mechanisms.
- Industrial demand announcements and execution. Steel plants, chemical companies, refineries that commit to hydrogen usage and build operational facilities.
- Hydrogen trade flows including export volumes, pricing, contracts for derivative fuels such as ammonia or synthetic fuels.
My Forecast Through 2040
Drawing together all pieces I present what I believe is the most likely path under a moderate acceleration scenario. Under that pathway by 2030 hydrogen energy will have made strong inroads in industrial sectors and in chemical feedstocks. Green hydrogen will begin to be competitive in favorable geographies for chemical and industrial heat by 2035. Transport uses will be visible in select segments such as heavy duty trucking long haul shipping or aviation derived fuels. Export-import trade will be functional in many regions. By 2040 hydrogen will supply a non negligible share of energy in hard to decarbonize sectors globally. Clean hydrogen production capacity will have scaled several fold compared with early 2020s levels. At the same time many of the early targets in less supportive regions will have been missed or delayed. Cost reduction will continue but cost gaps will remain for transport uses and for widespread heating or power generation.
Under a slower growth scenario many of the benefits will be more limited. Under high concerted global policy and investment a more ambitious scenario is possible where hydrogen becomes central in many more sectors and where cost gaps narrow faster.
Source Base and Evidence
I base this outlook on leading published reports and papers including those from the International Energy Agency such as the Global Hydrogen Review; from Bloomberg New Energy Finance hydrogen cost and supply reports; from national hydrogen strategies in Europe Asia Australia and North America; from industry research by major electrolysis manufacturers and chemical industrial groups; from independent monitors of project pipelines; and from literature on transport fuel alternatives and energy storage economics.
Conclusion
Hydrogen energy stands at an inflection point. Between now and 2040 its success will depend on cost reductions; on scaling infrastructure; on clarity and stability of policy; on regional advantages; on competition from other technologies. Hydrogen is unlikely to become a universal solution for all energy demand but it is poised to transform those sectors that are hardest to decarbonize. For businesses governments and investors those who anticipate hydrogen growth intelligently stand to benefit; those who assume that hydrogen is too difficult or too uncertain may miss opportunities.
