Where Green Hydrogen Goes First: Why Location Could Make or Break the Clean Fuel Transition

Green hydrogen has long been promoted as the missing piece of the deep decarbonization puzzle: a versatile, zero-carbon energy carrier that could, in principle, replace fossil fuels in steelmaking, ammonia synthesis, shipping, aviation and long-duration energy storage. Yet despite two decades of promises and a rapidly expanding pipeline of electrolyzer projects, actual demand for green hydrogen remains stubbornly thin. A new analysis published in Nature Reviews & Analysis | Energy argues that the bottleneck is not primarily one of supply or technology, but of geography — and that policies which ignore spatial realities are doomed to underperform. The study, titled “Spatially informed policies can accelerate green hydrogen demand,” makes the case that governments should stop treating hydrogen as a uniform commodity and start designing incentives around where hydrogen is cheapest to produce, where it is most valuable to use, and where infrastructure can realistically connect the two.

The core insight of the analysis is deceptively simple. The cost of producing hydrogen through electrolysis varies enormously across the planet, driven by the price and availability of renewable electricity, which itself depends on solar irradiance, wind capacity factors, land availability, grid carbon intensity and the timing of renewable generation. Electrolytic hydrogen produced in regions with abundant, cheap wind and solar power can cost a fraction of hydrogen produced where renewables are scarce or expensive. At the same time, the value of hydrogen differs sharply by end use and location: it is highest in industrial clusters that already consume large volumes of grey hydrogen, in ports serving international shipping, and in electricity systems where seasonal storage can displace gas-fired peaking capacity. Policies that flatten this spatial variation — for example, uniform national subsidies or undifferentiated production targets — waste public money by supporting projects in places where hydrogen will never be competitive, while starving the locations where early markets could actually take off.

The authors frame this as a coordination problem. Green hydrogen faces a classic chicken-and-egg dilemma: producers hesitate to build electrolyzers without guaranteed offtakers, while industrial consumers hesitate to convert their processes without assured, affordable supply. Spatially informed policy, the analysis contends, can break this deadlock by concentrating early support in a limited number of well-chosen hubs where production potential and demand density overlap. In such hubs, a single policy package — combining production incentives, offtake guarantees, shared pipeline and storage infrastructure, and streamlined permitting — can achieve economies of scale and learning effects that diffuse, geographically blind support schemes cannot. The approach mirrors lessons from other infrastructure transitions, where clustering early adopters around shared assets proved far more effective than scattering investments across the map.

Technically, the analysis builds on a growing body of spatially explicit energy system modeling. Unlike traditional national or regional models that average costs over large territories, spatially resolved models disaggregate the energy system into grid cells, each characterized by its own renewable resource profile, land constraints, water availability, existing infrastructure and demand density. When hydrogen production, conversion, transport and end use are optimized across thousands of such cells, striking patterns emerge. The cheapest production sites are often far from the largest demand centers, creating a transport cost gradient that fundamentally shapes which supply-demand pairings are economically viable. Hydrogen transport by pipeline is comparatively cheap over land but expensive across oceans, particularly if the hydrogen must first be converted to ammonia or a liquid organic carrier and then reconverted at the destination. These conversion penalties — often amounting to 30 to 50 percent of the delivered energy — mean that imported hydrogen will frequently struggle to compete with hydrogen produced close to where it is used, a conclusion with profound implications for the many national hydrogen strategies built around ambitious import targets.

This spatial lens also reframes the debate over which end uses should be prioritized. The analysis emphasizes that hydrogen’s value density varies by sector and by place. In fertilizer production, where ammonia plants are already concentrated in specific industrial regions, switching from grey to green hydrogen delivers immediate emissions reductions with minimal new infrastructure. In steelmaking, direct reduction of iron with hydrogen is technically mature and can be deployed where existing mills and skilled labor are located. By contrast, speculative uses such as blending hydrogen into natural gas grids or heating buildings deliver low carbon abatement per kilogram of hydrogen and are spatially inefficient, because the gas grid spreads demand thinly across territories where dedicated hydrogen infrastructure makes little economic sense. A spatially informed policy framework would therefore direct scarce green hydrogen toward dense, high-value industrial nodes first, allowing demand to scale before the fuel is asked to serve diffuse, low-value applications.

The policy instruments proposed in the analysis are correspondingly place-based. Production-side support, such as premium payments or contracts-for-difference for green hydrogen, should be calibrated to local production costs rather than set at a single national level, ensuring that support is sufficient to trigger investment in high-cost regions only where strategic value justifies it. Demand-side mandates and quotas should be phased in where industrial consumers are concentrated, creating guaranteed markets that de-risk private capital. Infrastructure planning should prioritize corridors connecting the best renewable resource zones to major industrial clusters and ports, with shared, open-access pipelines and storage lowering the entry barrier for smaller producers and users. Permitting regimes, often the silent killer of clean energy projects, should be accelerated within designated hydrogen hubs. The authors argue that such spatial targeting is not industrial policy by another name; it is simply an acknowledgment that energy systems are physical, and that the physics and economics of hydrogen are inseparable from geography.

The analysis also confronts the equity and geopolitical dimensions of spatial targeting. If green hydrogen production concentrates in a handful of resource-rich regions — the sun belts and wind corridors of the world — there is a real risk of replicating the fossil fuel era’s patterns of extraction and dependency, in which a few exporters supply many importers. The authors note that spatially explicit planning can mitigate these risks by identifying a broader portfolio of viable production regions, including many in the Global South that possess excellent renewable resources but lack the infrastructure and institutional support to exploit them. Development finance, capacity building and technology transfer targeted at these regions could diversify global supply, capture local value added, and prevent the green hydrogen economy from hardening into a new oligopoly. Conversely, importing countries that overestimate their future hydrogen needs and lock in long-term import contracts may find themselves stranded with expensive supply as domestic production costs fall.

Timing emerges as another critical variable. The analysis stresses that early demand creation matters more than early production capacity, because demand signals are what attract private investment along the entire value chain — electrolyzer manufacturing, renewable buildout, storage and transport. Policies that subsidize supply without cultivating committed offtake have, in the authors’ assessment, produced a global landscape of announced but unbuilt projects. Spatially informed demand-side instruments — such as quotas requiring a rising share of green hydrogen in ammonia, methanol and refinery feedstocks within defined industrial clusters — create the bankable revenue streams that financiers require. Once a handful of hub markets reaches critical mass, learning curves in electrolyzer manufacturing and renewable deployment can drive costs down globally, and the geography of competitiveness will gradually expand outward from the initial strongholds.

For researchers, the analysis issues a methodological challenge: energy models that cannot resolve space are increasingly inadequate for hydrogen policy design. The authors call for wider adoption of high-resolution, open datasets on renewable resources, grid infrastructure and industrial demand, and for model intercomparison exercises that test how sensitive policy conclusions are to spatial assumptions. For policymakers, the message is more direct. The green hydrogen transition will not be won by the country with the most generous blanket subsidy or the most sweeping national strategy, but by those who identify the right places, match supply to demand with physical infrastructure, and concentrate support where each public dollar buys the most abatement. In a technology where costs remain high and margins thin, geography is not a detail — it is the strategy.

Subject of Research: Spatially informed policy design to accelerate green hydrogen demand

Article Title: Spatially informed policies can accelerate green hydrogen demand

Article References: Spatially informed policies can accelerate green hydrogen demand. (n.d.). https://doi.org/10.1038/s41560-026-02139-x

Image Credits: AI Generated

DOI: 10.1038/s41560-026-02139-x

Keywords: green hydrogen, spatial policy, electrolysis, hydrogen hubs, renewable energy, industrial decarbonization, energy system modeling, hydrogen infrastructure, energy transition, hydrogen demand, Spatially, informed