Few sustainability sectors generate as much simultaneous enthusiasm and doubt as green hydrogen. Produced by splitting water with renewable electricity, it promises to decarbonise the industries that batteries cannot easily reach — steel, ammonia, heavy transport, long-duration storage. Whether that promise translates into a bankable market depends on details that headline forecasts routinely skip, and the gap between the optimistic and pessimistic cases is wide enough that both camps can cite real evidence.
The productive approach is to be specific about where green hydrogen genuinely wins, what governs its economics, and what separates a defensible investment case from expensive optimism.
The mistake that fuels the skepticism
Much of the doubt around green hydrogen comes from treating it as a universal solution — a drop-in decarbonisation answer for everything from home heating to passenger cars. In most of those applications, direct electrification is cheaper and more efficient, and hydrogen loses on straightforward thermodynamics. Every conversion step — electricity to hydrogen, hydrogen to storage, storage back to useful energy — loses energy, and where a battery or a heat pump can do the job directly, hydrogen's round-trip inefficiency is a decisive disadvantage.
Positioning hydrogen as an everything-solution invites exactly the skepticism it has received, because in the broad case it genuinely doesn't pencil. The credible case is narrower and stronger.
Where green hydrogen genuinely wins
Green hydrogen's real advantage lies in hard-to-abate applications where no cheaper decarbonisation pathway exists. As a feedstock, it can replace grey hydrogen in ammonia production and displace coking coal in green-steel processes — sectors where the chemistry demands hydrogen or a hydrogen derivative, not just energy. As a carrier, it enables decarbonisation where direct electrification is impractical: certain heavy transport, long-duration and seasonal storage, and industrial heat at temperatures electricity struggles to reach economically.
In these niches, demand is grounded in industrial necessity rather than speculation. A steelmaker facing carbon costs and a green-premium market has a concrete reason to buy green hydrogen that has nothing to do with hydrogen's general merits. This is where the durable demand lives, and it's where serious market analysis should concentrate.
The cost curve is the whole story
The economics of green hydrogen turn almost entirely on delivered cost, which is a function of three variables: electrolyser capital cost, renewable electricity price, and utilisation rate. As electrolyser manufacturing scales and renewable power costs decline, the delivered cost of green hydrogen falls — but the pace of that decline varies enormously by region, and any serious market view has to model these curves rather than assume a single global number.
The regional variation is the crux. A location with abundant, cheap renewable electricity and high electrolyser utilisation can approach cost parity with grey hydrogen far sooner than a location with expensive or intermittent power. This is why green hydrogen's competitiveness is not a single date but a map — some regions cross into viability years ahead of others, and the geography of where cheap green hydrogen can be produced will reshape which industries relocate to access it.
Electrolyser utilisation deserves particular attention because it interacts with the renewable-power question in a way that's often glossed over. Running an electrolyser only when renewable power is cheap maximises the cost advantage per unit of input electricity but lowers utilisation, spreading the capital cost over less output. Running it continuously raises utilisation but forces the purchase of higher-cost power during non-renewable hours. The optimal point is site-specific and central to the delivered-cost calculation.
Infrastructure is the gating factor
Production is only half the equation. Storage, transport, and end-use infrastructure remain underbuilt, and this gap governs how quickly demand can actually be met even where production economics work.
Hydrogen is difficult to store and move. It requires high-pressure or cryogenic storage, or conversion to a carrier like ammonia, each adding cost and complexity. Pipeline networks designed for hydrogen are limited. End-use equipment — hydrogen-ready steel plants, ammonia synthesis retrofits, fuelling infrastructure — is still being built. The markets that build offtake and infrastructure in parallel with production will realise value years ahead of those that build production capacity alone and then discover they can't move or sell the output.
This sequencing problem is one of the clearest signals separating serious projects from speculative ones. A green hydrogen project with a contracted offtaker and a viable delivery route is a fundamentally different proposition from an electrolyser built on the assumption that demand and infrastructure will materialise.
Reading the market with discipline
Green hydrogen rewards discipline over enthusiasm. The capital flowing into the sector is real, and so is the risk of stranded assets in applications where cheaper alternatives exist or where infrastructure never arrives to connect production to demand. Rigorous Due Diligence — grounded in application-level demand and regional cost curves rather than aggregate global projections — is what separates sound positioning from optimism that doesn't survive contact with delivered economics.
For investors and industrial buyers, the questions that carry the most signal are concrete. Which specific application is the demand grounded in, and is that application one where hydrogen genuinely beats the alternatives? What is the delivered cost at this specific location, given local power prices and realistic utilisation? Is there contracted offtake, or is demand assumed? And does the infrastructure exist to connect production to end use, or is that a separate project entirely?
The honest framing is that green hydrogen is neither the universal solution its boosters describe nor the dead end its critics claim. It is a genuinely important decarbonisation tool for a specific set of hard-to-abate applications, whose economics are improving unevenly across regions, and whose real-world deployment is paced as much by infrastructure and offtake as by production cost. Analysis that holds all of those truths at once is the analysis worth acting on.