Market Size, Capacity & Growth

Green hydrogen is hydrogen split from water by electrolysis, using renewable electricity, so the process emits close to no carbon. The sector is early and moving unevenly, which is exactly why a plan grounded in real numbers wins funding while a plan built on optimistic projections does not. Global installed water-electrolysis capacity reached roughly 2 gigawatts (GW) in 2024, with more than 1 GW added on top through the first half of 2025, according to the IEA Global Hydrogen Review 2025. Manufacturing capacity for electrolysers has grown fast, from about 0.6 GW in 2021 to around 4.9 GW today.

The scale gap is the story. Low-emissions hydrogen production grew about 10% in 2024 and is on track to reach roughly 1 million tonnes (Mt) in 2025, yet that is still under 1% of total hydrogen supply, most of which remains "gray" hydrogen made from unabated natural gas (IEA, 2025). Delivering the full announced project pipeline by 2030 would require around 420 GW of electrolysis and more than $1,500 billion of investment, according to the IEA's production prospects analysis. That is roughly the size of all new power-generation investment worldwide in a single year, which tells you two things: the ambition is enormous, and most of it is not yet financed. Your plan lives in that financing gap.

Geography matters more here than in almost any other startup category. China now accounts for about 65% of installed electrolysis capacity and nearly 60% of global electrolyser manufacturing capacity (IEA, 2025). For a Western founder, that concentration is both a threat, cheaper Chinese equipment undercuts Western suppliers, and an opportunity, because domestic-content and subsidy rules in the US and Europe reward local sourcing. A serious plan states which equipment supply chain you are betting on and why.

What changed to make this a business rather than a research topic is the arrival of durable revenue support. Before 2023 a green hydrogen plant was a science project with no way to close the four-dollar gap against gray hydrogen. The US 45V production credit and the UK Hydrogen Allocation Rounds turned that gap into a policy-backed subsidy, and that single shift is why capital is now moving into the sector, unevenly, but for the first time at scale. The IEA's 2025 review is candid that the ramp is slower than governments hoped; the pipeline is enormous but most of it has not reached final investment decision. For a founder, a slower ramp is not bad news. It means fewer competitors have closed financing, offtakers are still choosing partners, and a focused, well-structured plan can still win a place in a HAR round or a 45V-backed project before the field crowds.

A few named projects set the ceiling on ambition. The NEOM Green Hydrogen Company in Saudi Arabia, a joint venture of ACWA Power and Air Products, is a roughly 4 GW, $8.4 billion plant with first ammonia product expected in 2027. In the US, Plug Power runs the Hidrogenii joint venture with Olin producing about 15 tonnes a day. On the equipment side, Nel ASA (Norway), ITM Power (UK PEM systems), Cummins and majors including Air Liquide, Air Products, ENGIE, Uniper and Siemens Energy anchor the supply chain. You will not out-scale these companies, so your plan should show where a focused, offtake-anchored entrant wins on speed and local relationships instead.

Quick Answers Buyers Search For

Before founders write a plan, they usually want five questions settled. Here they are, answered with the same figures a lender would check.

Is green hydrogen actually profitable yet?

On a pure spot basis, rarely. Merchant green hydrogen costs roughly $4 to $8 per kilogram to make in Western markets, while gray hydrogen sits near $1 to $1.50 per kg. Profit appears when a production credit or fixed-premium subsidy narrows that gap and a buyer commits to a price above your net cost. That is why the funding chapter of a green hydrogen plan carries more weight than the marketing chapter.

Why is electricity the number that decides everything?

Electricity is typically 60 to 70% of the levelised cost of hydrogen. A plant needs roughly 50 to 55 kWh of electricity to make one kilogram of hydrogen. So if power costs $40 per MWh, that is about $2.00 to $2.20 of electricity in every kilogram before you count capex, water, maintenance or financing. Halve the power price and you transform the economics; the plan should show the power contract before the sales forecast.

How big does a plant have to be to matter?

Physical plants are measured in megawatts of electrolyser capacity, not in dollars of revenue. A 1 MW system produces roughly 150 to 200 tonnes of hydrogen a year at a realistic capacity factor. A 5 MW plant, common for a first commercial project tied to a single offtaker, produces closer to 800 to 1,000 tonnes. Nameplate is not output; capacity factor is.

What kills most green hydrogen business plans at diligence?

Three things: no signed offtake, an assumed power price with no contract behind it, and revenue modelled at nameplate capacity rather than realistic utilisation. Each is avoidable, and the template below flags all three.

What It Costs to Build

Green hydrogen has an unusually wide cost range because it covers everything from a two-person trading and consulting business to a utility-scale production plant. A pilot, brokerage or advisory venture can start near $90,000 (about £70,000). A physical production plant is priced per megawatt of electrolyser capacity, and the swing between technologies and regions is dramatic.

Alkaline systems run roughly $0.3 million per MW from Chinese suppliers and $1.3 million per MW in Europe and North America. PEM systems, which handle variable renewable power better, cost more, commonly $1.5 million to $3 million per MW in Western markets. Real-world projects in 2024 averaged around $3,000 per kW of installed system cost, per the electrolyzer cost analysis published by the US Department of Energy Hydrogen Program. On those numbers a 5 MW Western PEM plant, with compression, storage and dispensing, typically lands between $8 million and $18 million before any subsidy.

Cost Breakdown for a First Commercial Plant

• Electrolyzer stack + balance of plant: $0.3M/MW (Chinese alkaline) to $1.5M–$3M/MW (Western PEM) - the single biggest line item
• Renewable power supply (PPA or on-site solar/wind): not a lump sum but 60–70% of lifetime cost; the contract terms drive the whole model
• Compression, storage & dispensing: $0.3M–$1.5M depending on pressure and offtake format (gaseous, liquid, pipeline)
• Feasibility, permitting & grid interconnection: $50K–$400K, and interconnection queues can dominate the timeline
• Working capital & offtake development: $40K–$300K to carry the business to first revenue and lock in buyers

Funding Routes That Fit This Niche

In the US, the decisive lever is the Section 45V Clean Hydrogen Production Tax Credit, worth up to $3.185 per kilogram in 2025 for the cleanest tier, with final rules issued by the Treasury and IRS in January 2025. Debt from the DOE Loan Programs Office, project equity from infrastructure funds, and standard SBA 7(a) loans (up to $5 million) for the smaller trading, service or refuelling operations all play a role. For a capital-heavy plant, most founders combine grant money, a production credit, and project-finance debt against a signed offtake.

In the UK, revenue support flows through the Hydrogen Production Business Model and its Low Carbon Hydrogen Agreement, a Contract for Difference administered by the Low Carbon Contracts Company (LCCC) and awarded through the Hydrogen Allocation Rounds (GOV.UK). The second round, HAR2, shortlisted 27 projects representing about 765 MW on 7 April 2025, with awards expected in early 2026. For pre-plant capital, the UK's Start Up Loans scheme offers up to £25,000 at 6% fixed with mentoring. Elsewhere, the European Hydrogen Bank runs fixed-premium subsidy auctions per kilogram, and export-scale developers benchmark against the NEOM structure in Saudi Arabia.

Three Ways to Enter the Market

Founders often assume a green hydrogen business means owning a plant. It does not. The three entry models below carry very different capital, timeline and risk, and the plan should commit to one rather than blur them.

For most first-time founders, the offtake-anchored model is the only version that gets financed at plant scale, because it removes the price exposure lenders fear. The equipment and service model is where lean, self-funded entrants realistically start: refuelling operators, electrolyzer installers and maintenance specialists earn from producers scaling up without carrying the plant's capital burden. Pure merchant production is the hardest to fund and should never appear in a plan without a hedging or subsidy story attached.

Revenue, LCOH & Unit Economics

Every green hydrogen model reduces to one number a diligence team will rebuild themselves: the levelised cost of hydrogen (LCOH), the all-in cost per kilogram across the plant's life. It bundles electrolyzer capex, electricity, water, maintenance and financing. Electricity dominates at 60 to 70%, which is why the power contract is the first thing a serious investor asks about.

Western merchant LCOH commonly sits around $4 to $5 per kilogram today. The 45V credit of up to $3.185 per kg can cut net cost below $1.50 per kg, which is where a fundable margin against gray hydrogen appears. Analysts note that a project paired with a zero-carbon power purchase agreement plus the full credit can, in favourable cases, drive net LCOH close to break-even against fossil hydrogen. The plan must show this arithmetic explicitly, not gesture at it.

A Worked Example: 5 MW PEM Plant

Take a 5 MW PEM plant running at a 55% capacity factor, which is realistic when power is partly grid-linked and partly renewable. That plant produces roughly 480 tonnes of hydrogen a year, or about 480,000 kilograms. Assume an unsubsidised LCOH of $4.50 per kg.

• Annual output: ~480,000 kg at 55% capacity factor
• Unsubsidised cost to produce: ~$2.16M/yr at $4.50/kg
• 45V credit at $3.185/kg: ~$1.53M/yr, cutting net cost to roughly $0.63M or about $1.31/kg
• Sell at $3.00/kg on a contract: ~$1.44M revenue against ~$0.63M net cost after credit
• Result: a merchant sale that loses money before subsidy becomes a positive-margin business after it

The lesson is blunt: the same physical plant is a loss-maker or a viable business depending entirely on the power price, the capacity factor, and whether you qualify for and can monetise the credit. Merchant net margins in this niche realistically run 5 to 16% once you strip out subsidy timing; equipment and service models run higher because they carry no fuel cost. A green hydrogen plan that does not stress-test all three of those levers is not ready for an investor.

Secondary revenue matters too. Producers sell oxygen, a byproduct of electrolysis, into industrial and medical markets; they earn guarantee-of-origin or clean-fuel certificates; and refuelling operators layer dispensing margin on top of the molecule. Model these as upside, not as the reason the base case works.

It is worth being precise about how those streams behave, because investors will probe them. Oxygen is genuine revenue but thin and local: it only pays if there is a nearby buyer, since transporting it erodes the value quickly. Clean-fuel and guarantee-of-origin certificates can be meaningful in markets with a compliance mandate behind them, but their price is policy-dependent and can move, so a plan that leans on certificate revenue should show what the base case looks like without it. Dispensing and service margin, by contrast, is durable and controllable, which is one reason the equipment-and-service entry model is easier to fund than merchant production. The discipline across all of these is the same: name each stream, size it conservatively, and make clear the plant is viable on its core hydrogen sale before any of the extras are counted. A forecast that only works once you add speculative byproduct income is a forecast that does not work.

Policy, Permits & Standards

Green hydrogen sits at the intersection of energy, industrial safety and climate policy, so the regulatory chapter is longer than most sectors and carries real financial weight, because it is where the subsidy lives.

United States

• Section 45V Clean Hydrogen Production Tax Credit - up to $3.185/kg (2025) for hydrogen under 0.45 kg CO2e/kg meeting prevailing wage and apprenticeship rules; tiered down through $1.065, $0.795 and $0.635/kg. Final Treasury and IRS rules issued January 2025. Credit runs 10 years from the plant entering service. You must prove lifecycle emissions with an approved model, not simply assert them.
• OSHA Process Safety Management (PSM) - hydrogen is a flammable, high-pressure gas; PSM compliance is mandatory above threshold quantities
• EPA air and water permits - for the facility and any grid or on-site generation
• DOT / PHMSA transport rules - for moving compressed or liquefied hydrogen by road
• Grid interconnection - often the longest single item on the timeline; model it as 12–24 months, not weeks

United Kingdom

• Hydrogen Production Business Model + Low Carbon Hydrogen Agreement - a Contract for Difference administered by the Low Carbon Contracts Company, bridging the gap between low-carbon hydrogen cost and high-carbon fuel prices
• Hydrogen Allocation Rounds - the route to revenue support; HAR2 shortlisted 27 projects (~765 MW) on 7 April 2025 with awards expected early 2026; HAR3 signalled to follow
• UK Low Carbon Hydrogen Standard - you must evidence the emissions intensity of your hydrogen to qualify for support
• Environment Agency permits + HSE safety case - site permits and a hydrogen-specific safety assessment
• DESNZ engagement - the department sets strategy, allocation timing and the standard itself

European Union & Beyond

In the EU, hydrogen made for transport and industry must meet the Renewable Fuels of Non-Biological Origin (RFNBO) rules under the Renewable Energy Directive, which impose additionality plus temporal and geographic correlation tests on the electricity you use, roughly, your power must be genuinely new renewable capacity and matched to your production in time and place. The European Hydrogen Bank then auctions a fixed premium per kilogram to close the cost gap. In the Gulf, the NEOM Green Hydrogen Company (ACWA Power and Air Products) shows the export-oriented, ammonia-carrier model at 4 GW scale. Whichever jurisdiction you target, the plan should name the specific support mechanism you are relying on and the emissions threshold you must hit to qualify.

Hydrogen Terms, Defined

Investors expect founders to use these terms precisely. Mixing them up signals inexperience, so the plan should read like someone who knows the difference.

• LCOH (Levelised Cost of Hydrogen): all-in cost per kilogram across the plant's life, covering capex, electricity, water, maintenance and finance. The single number diligence rebuilds.
• Electrolyzer: the device that splits water into hydrogen and oxygen using electricity. Sized in megawatts of input power.
• PEM (Proton Exchange Membrane): an electrolyzer type that ramps quickly and suits variable renewable power, but uses expensive precious-metal catalysts, so it costs more per kW.
• Alkaline electrolysis: the older, cheaper, more mature technology, better for steady baseload running.
• Capacity factor: the share of nameplate capacity actually used over a year. Revenue scales with this, not with the headline megawatts.
• Offtake agreement: a contract in which a buyer commits to purchase a set volume, often at a fixed or floor price. The backbone of a fundable plant.
• PPA (Power Purchase Agreement): a long-term electricity supply contract; the term and price largely determine your LCOH.
• Green vs gray vs blue hydrogen: green is made by electrolysis on renewable power; gray from unabated natural gas; blue from natural gas with carbon capture.

Who Actually Buys Green Hydrogen

A common weakness in green hydrogen plans is a vague "the world needs clean energy" demand story. Investors want to know which specific buyer signs the offtake, and different buyers value very different things. There are four demand clusters worth naming precisely, and your plan should pick the one or two your location and scale can realistically serve.

Heavy transport and refuelling is the most visible near-term buyer: bus and truck fleets, and the refuelling stations that serve them, need hydrogen delivered at consistent pressure and purity. These customers care about reliability and dispensing logistics more than headline price, and they usually want a supplier within trucking distance. Industrial and chemical offtakers, ammonia and methanol producers, refineries and steelmakers, buy at larger volumes and negotiate hard on price, but they offer long contracts that anchor a project. Power and grid balancing buyers use hydrogen as long-duration storage, converting surplus renewable electricity into a molecule that can be stored and reburned; this segment is real but early. Finally, export and ammonia-carrier demand, the model NEOM is built for, only makes sense at gigawatt scale and is out of reach for most first-time founders.

The practical takeaway for a business plan is to quantify one anchor buyer in detail, their volume, their willingness to pay, their switching cost, and to treat the rest as expansion. A plant sized to a single credible offtaker will always be more fundable than one sized to an abstract market forecast. This is where positioning clarity, more than technology choice, decides whether a green hydrogen venture converts investor interest into a signed cheque.

Operations, Supply Chain & Timeline

The operations chapter is where a green hydrogen plan proves the founder understands the physical business rather than the concept. Four operational realities deserve their own paragraphs because they routinely surprise first-time developers.

Power comes first, always

Because electricity is 60 to 70% of your cost, the power arrangement is the operational spine. The plan should specify whether power comes from an on-site solar or wind installation, a corporate Power Purchase Agreement, the grid, or a hybrid, and it should state the price and term. A plant that runs only when the sun shines has a low capacity factor and high per-kilogram cost; a grid-connected plant can run more hours but must satisfy additionality and correlation rules to earn subsidy in the EU and to hit the cleanest 45V tier in the US.

Electrolyzer lead times and sourcing

Electrolyzer supply is a genuine constraint. Western PEM and alkaline suppliers such as Nel, ITM Power, Cummins and Siemens Energy carry order backlogs, while Chinese alkaline systems are cheaper but raise domestic-content and warranty questions that affect subsidy eligibility. The plan should name the intended supplier or shortlist, the technology, and a realistic delivery lead time, often 9 to 18 months for Western equipment at commercial scale.

Storage, compression and delivery format

Hydrogen is light and hard to store. The plan must state how the product reaches the customer: compressed gas by tube trailer, liquefied for longer distances, or piped to an adjacent offtaker. Each format changes the capex, the safety case and the customer set. Co-locating the plant next to the anchor buyer removes a large slice of delivery cost and risk, which is why so many credible projects sit inside industrial clusters.

Grid interconnection and permitting timeline

Grid interconnection is frequently the longest single item on the critical path, running 12 to 24 months in many markets, and it can be the reason a well-financed project slips a year. A realistic timeline, feasibility and permitting in months 1 to 9, equipment procurement and grid works in months 6 to 24, commissioning and ramp thereafter, reads as competence to a lender. An 18-month build stated as six months reads as naivety and undermines the entire forecast.

Five Mistakes That Sink Green Hydrogen Plans

Across cleantech plans we have reviewed, the same avoidable errors recur. Each one is a reason a diligence team stops reading, and each is fixable before you send the plan.

• Modelling LCOH without a firm power price. Electricity is the majority of your cost. A forecast with an assumed power number and no PPA behind it is treated as fiction. Lock the power story before the sales story.
• Assuming the full 45V credit without proving emissions. The top $3.185/kg tier requires lifecycle emissions under 0.45 kg CO2e/kg, evidenced with an approved model. Plans that bank the full credit on a grid-connected plant with no clean-power matching lose credibility instantly.
• Sizing revenue at nameplate capacity. A 5 MW plant does not run 8,760 hours a year. Model a realistic 40 to 60% capacity factor, or your revenue line is overstated by nearly half.
• Choosing PEM by reflex. PEM is fashionable, but if your duty cycle is steady, a lower-capex alkaline system can improve the economics materially. The plan should justify the technology against the duty cycle, not the trend.
• Building a merchant plant with no offtake. Price exposure with no committed buyer is the fastest route to a rejected plan. Secure at least a heads-of-terms offtake covering a meaningful share of year-one volume before financial close.

How the Money Actually Stacks

Green hydrogen is a project-finance business, not a venture business, and the difference shapes the whole plan. A software startup raises equity and burns it; a hydrogen plant assembles a capital stack in which each layer has different risk tolerance and cost. Getting that stack right is the practical work behind a fundable plan, and it is the part first-time founders most often skip.

A typical first commercial plant blends four sources. Grant funding, from national programmes or the European Hydrogen Bank, reduces the equity needed and de-risks early works; it is competitive and slow, so the plan should treat it as probable rather than certain. Revenue support, the US 45V credit or the UK Contract for Difference, is what makes the operating economics work, but it flows against production, so it improves cash flow over time rather than funding the build. Project debt, from infrastructure lenders or a facility like the DOE Loan Programs Office, provides the bulk of construction capital, but it demands a signed offtake and a credible LCOH before it commits. Founder and sponsor equity, usually 15 to 30% of the total, carries the highest risk and the highest return, and its size signals conviction to every other party.

The order matters. Lenders will not close without an offtake; grant bodies want to see co-investment; the production credit only monetises once you produce. A plan that sequences these correctly, equity and grant to reach financial close, debt to build, and revenue support to sustain operations, reads as investable. A plan that lumps them into a single "funding required" number does not. This is precisely the structure Avvale builds into the financial model that ships with the paid packages, so the capital stack, the drawdown schedule and the subsidy timing all reconcile against the five-year forecast.

One more discipline separates strong plans from weak ones: an explicit downside case. What happens to the model if the power price rises 20%, if the capacity factor lands at 45% instead of 55%, or if the credit is delayed a year? Investors do not expect a project with no risk; they expect a founder who has quantified the risk and shown the business survives a reasonable stress. A green hydrogen plan that presents a single optimistic line, with no sensitivity on power price or utilisation, tells a diligence team the founder has not yet done the hard thinking. The template prompts you to build that downside case rather than hope nobody asks for it.

Sample Business Plan Preview

Here is an extract from a green hydrogen business plan written by our team, so you can see exactly what a fundable version looks like:

What's in the Template

Every Avvale business plan template includes these sections, pre-structured for the green hydrogen model and its funding requirements:

• Executive Summary - plant scale, offtake, LCOH target and funding ask in one page an investor reads first
• Company Overview - legal structure, technology choice (PEM vs alkaline) and the reasoning behind it
• Market Analysis - capacity, growth and policy context, cited to the IEA and government sources
• Offtake & Customer Analysis - named buyer segments (transport, chemicals, ammonia, refuelling) and demand triggers
• Competitive Position - where a focused entrant wins against Air Liquide, Air Products, Nel, ITM and regional independents
• Operations Plan - power contract, capacity factor, storage, dispensing and grid interconnection timeline
• Regulatory & Funding Plan - 45V, HAR, RFNBO or the specific mechanism you rely on, with emissions-threshold evidence
• Management Team - founder engineering credentials, developer partnership and advisory board

The optional Financial Forecast add-on (included in our $300/£250 and $1,000/£800 packages) provides a 5-year Excel model with LCOH build-up, capacity-factor sensitivity, subsidy monetisation, income statement, cash flow, balance sheet, break-even analysis and the startup capital requirement, the exact outputs a hydrogen lender or grant assessor expects to see.

Want the wider library first? Start with our free business plan template hub, or compare the fully written option on the bespoke business plan page. Founders in adjacent clean-energy niches often pair this with our market research and content service to get cited industry data written into the plan.

Frequently Asked Questions