Myths vs realities: green hydrogen — what the evidence actually supports

Global green hydrogen production capacity reached approximately 2.1 GW by end of 2025, yet that figure represents less than 1% of total hydrogen output worldwide (IEA, 2025). Meanwhile, announced project pipelines exceed 420 GW globally, with over $570 billion in investment commitments through 2030 (Hydrogen Council, 2025). The gap between ambition and deployment has fueled both unbridled optimism and deep skepticism, often grounded in outdated assumptions. Separating fact from fiction requires examining what the latest evidence actually shows about green hydrogen's costs, efficiency, scalability, and role in the energy transition.

Why It Matters

Hydrogen is the most abundant element in the universe, yet producing it cleanly at scale remains one of the hardest problems in the energy transition. Roughly 95 million tonnes of hydrogen are consumed annually for industrial processes like ammonia synthesis, oil refining, and methanol production, with nearly all of it produced from unabated fossil fuels (IRENA, 2024). This "grey hydrogen" generates approximately 900 million tonnes of CO2 per year, equivalent to the combined emissions of the United Kingdom and Indonesia.

Green hydrogen, produced by splitting water using renewable electricity through electrolysis, offers a pathway to decarbonize these hard-to-abate sectors. But it also carries significant technical and economic challenges that advocates sometimes understate and critics sometimes exaggerate. Getting the analysis right matters because investment decisions being made today, often involving billions of dollars of public subsidies, will lock in infrastructure and supply chains for decades.

Policymakers in the EU, US, and Asia have collectively committed over $100 billion in hydrogen subsidies and incentives since 2020 (BloombergNEF, 2025). Whether these investments deliver genuine climate benefits or become expensive stranded assets depends on understanding where green hydrogen genuinely outperforms alternatives and where other solutions like direct electrification are more effective.

Key Concepts

Green hydrogen refers specifically to hydrogen produced via electrolysis powered by renewable electricity. It is distinct from grey hydrogen (natural gas reforming without carbon capture), blue hydrogen (natural gas reforming with carbon capture and storage), and pink hydrogen (nuclear-powered electrolysis). The color taxonomy, while imperfect, helps distinguish production pathways with very different carbon footprints.

Electrolyzers are the core technology. Three main types dominate: alkaline electrolyzers (mature, lower cost, slower response), proton exchange membrane (PEM) electrolyzers (faster response, higher cost, smaller footprint), and solid oxide electrolyzers (highest efficiency but still at demonstration scale). Global electrolyzer manufacturing capacity reached approximately 45 GW per year by late 2025, up from under 10 GW in 2022 (IEA, 2025).

The levelized cost of hydrogen (LCOH) captures total production cost per kilogram, including capital expenditure, electricity costs, operations, and financing. Electricity typically accounts for 50 to 70% of green hydrogen's LCOH, making cheap renewable power the single most important cost driver.

Myth 1: Green hydrogen is too expensive to compete with fossil fuels

Reality

Green hydrogen costs have declined substantially but remain above grey hydrogen in most markets. As of mid-2025, green hydrogen production costs range from $3.50 to $6.00 per kilogram in most regions, compared to $1.00 to $2.50 per kilogram for grey hydrogen (BloombergNEF, 2025). However, the cost trajectory is sharply downward. IRENA projects green hydrogen reaching $1.50 to $3.00 per kilogram by 2030 in regions with excellent renewable resources, driven primarily by falling electrolyzer costs (down 40% since 2020) and cheaper renewable electricity.

Several projects are already approaching cost parity in favorable locations. NEOM Green Hydrogen Company in Saudi Arabia, a joint venture between ACWA Power, Air Products, and NEOM, is constructing a $8.4 billion facility targeting production costs below $3.00 per kilogram using dedicated solar and wind resources. In Chile, HIF Global's Haru Oni project leverages some of the world's cheapest wind power to produce green hydrogen at costs competitive with blue hydrogen.

The comparison also shifts when carbon pricing enters the picture. With the EU Emissions Trading System carbon price averaging above EUR 65 per tonne in 2025, grey hydrogen's effective cost rises by $0.50 to $0.90 per kilogram, narrowing the gap considerably. The US Inflation Reduction Act's 45V production tax credit of up to $3.00 per kilogram makes green hydrogen immediately cost-competitive in the American market for qualifying projects.

KPI	2022 Baseline	2025 Actual	2030 Target
Green H2 LCOH ($/kg)	$5.00 to $8.00	$3.50 to $6.00	$1.50 to $3.00
Electrolyzer CAPEX ($/kW)	$1,200 to $1,800	$700 to $1,100	$300 to $500
Electrolyzer efficiency (kWh/kg H2)	52 to 58	48 to 55	42 to 48
Global electrolyzer capacity (GW/yr)	<10	~45	100+

Myth 2: Hydrogen is always less efficient than direct electrification

Reality

This myth contains a kernel of truth but is applied far too broadly. For applications where direct electrification is feasible, such as passenger vehicles, space heating in moderate climates, and light industry, batteries and heat pumps are indeed 2 to 3 times more energy-efficient than hydrogen pathways. A battery electric vehicle converts roughly 80% of grid electricity to wheel motion, while a hydrogen fuel cell vehicle converts only about 30 to 35% (including electrolysis, compression, and fuel cell losses).

However, the efficiency argument breaks down in sectors where direct electrification faces fundamental physical or economic barriers. Steel production requires temperatures exceeding 1,500 degrees Celsius and a chemical reducing agent, functions that hydrogen can serve but batteries cannot. Ammonia synthesis (essential for fertilizer feeding roughly half the world's population) requires hydrogen as a feedstock, not merely as an energy carrier. Maritime shipping on transoceanic routes demands energy densities that current battery technology cannot provide at economically viable weight and volume.

A 2024 analysis by the Potsdam Institute for Climate Impact Research found that hydrogen and its derivatives are the lowest-cost decarbonization pathway for approximately 15 to 20% of global final energy demand, primarily in heavy industry, long-distance transport, and chemical feedstocks (Ueckerdt et al., 2024). The key insight is selectivity: green hydrogen should target applications where no viable electric alternative exists, rather than competing with electrification across the board.

Myth 3: Green hydrogen will power the entire transportation sector

Reality

Early hydrogen hype envisioned fuel cell vehicles replacing internal combustion engines across all transport segments. The evidence now clearly shows a more nuanced picture. Battery electric vehicles dominate light-duty transport, with global EV sales surpassing 17 million units in 2024 (IEA, 2025). Hydrogen fuel cell passenger cars, by contrast, numbered fewer than 80,000 cumulative sales worldwide through 2025, with Hyundai and Toyota as the only major manufacturers still producing them.

Where hydrogen does show genuine transport promise is in heavy-duty, long-range, and high-utilization applications. Hyundai's XCIENT Fuel Cell trucks have logged over 10 million kilometers in commercial service across Switzerland, Germany, and South Korea since 2020, demonstrating viability for regional freight. Nikola Corporation began commercial deliveries of its hydrogen fuel cell Class 8 trucks in late 2024, targeting long-haul routes where battery weight penalties reduce payload capacity.

Aviation and maritime shipping represent the most promising transport use cases for hydrogen derivatives. Maersk has ordered 25 methanol-capable container vessels, with green methanol produced from green hydrogen and captured CO2 serving as the primary alternative fuel. Airbus plans to introduce its ZEROe hydrogen-powered aircraft by 2035, targeting short and medium-haul routes. These applications leverage hydrogen's high gravimetric energy density (roughly three times that of jet fuel by weight) in contexts where batteries remain impractical.

Myth 4: We do not have enough renewable electricity to produce green hydrogen at scale

Reality

Scaling green hydrogen to replace all current grey hydrogen production (approximately 95 million tonnes per year) would require roughly 3,600 TWh of renewable electricity, equivalent to about 12% of 2025 global electricity generation. That is a substantial figure, but it must be contextualized within the broader renewable energy buildout already underway.

Global renewable electricity capacity additions hit a record 560 GW in 2024 (IRENA, 2025), and annual additions are projected to exceed 700 GW by 2028. Solar PV module costs fell below $0.10 per watt in late 2024, making dedicated renewable capacity for hydrogen production increasingly affordable. Regions with exceptional renewable resources, including the Middle East, North Africa, Patagonia, and western Australia, can generate solar or wind power at capacity factors of 30 to 50%, producing green hydrogen at costs that justify long-distance export.

The real constraint is not total renewable potential but competition for that electricity. Every megawatt-hour used for hydrogen is a megawatt-hour not directly decarbonizing the power grid, transport, or buildings. This "opportunity cost" argument, raised prominently by researchers at the Oxford Institute for Energy Studies, suggests hydrogen production should primarily use additional renewable capacity rather than diverting existing clean electricity from higher-efficiency end uses. Projects like the Western Green Energy Hub in Australia, planning 50 GW of dedicated wind and solar for hydrogen export, exemplify this additionality principle.

Myth 5: Green hydrogen is just a fossil fuel industry distraction

Reality

This critique has some validity but oversimplifies a complex landscape. Several oil and gas majors have indeed used hydrogen announcements to deflect pressure for near-term emissions reductions. Shell scaled back its hydrogen division in 2023, and BP reduced its hydrogen ambitions amid a broader pivot back toward fossil fuel production. A 2024 analysis by Oil Change International found that fossil fuel companies' hydrogen investments represented less than 2% of their total capital expenditure, suggesting limited commitment.

However, dismissing all hydrogen development as greenwashing ignores legitimate decarbonization applications and the significant investment from non-fossil-fuel actors. Fortescue, the Australian mining company, has committed over $6.2 billion to its green hydrogen and green ammonia business through Fortescue Energy, commissioning its first commercial-scale electrolyzer facility in Gladstone, Queensland in 2025. Plug Power, a dedicated hydrogen technology company, operates the largest PEM electrolyzer manufacturing facility in the world in Rochester, New York, with 100 tonnes per day of green hydrogen production capacity under development.

Government-backed initiatives also demonstrate genuine commitment. The EU's European Hydrogen Bank conducted its first auction in 2024, awarding EUR 720 million in subsidies to seven green hydrogen projects across Europe. India's National Green Hydrogen Mission has allocated $2.3 billion to develop 5 million tonnes of annual production capacity by 2030. Japan's revised hydrogen strategy targets 12 million tonnes of annual supply by 2040, backed by $15 billion in public investment.

The evidence suggests that while fossil fuel company hydrogen claims warrant skepticism, the broader ecosystem of governments, technology companies, and industrial end users is pursuing green hydrogen for substantive decarbonization reasons.

What the Evidence Shows

The peer-reviewed literature and market data converge on several conclusions. Green hydrogen is not a universal solution and should not be deployed where direct electrification is more efficient and cost-effective. It is, however, an essential tool for decarbonizing the roughly 15 to 20% of global emissions that electrification alone cannot reach, primarily in heavy industry, chemical production, and long-distance transport.

Cost reductions are real but depend heavily on continued policy support, electrolyzer manufacturing scale-up, and access to cheap renewable electricity. The gap between announced projects and final investment decisions remains wide: of the 420+ GW in announced pipeline, only about 15 GW had reached FID by end of 2025 (Hydrogen Council, 2025). Closing this gap requires resolving permitting delays, establishing clear certification standards for hydrogen's carbon intensity, and building transport and storage infrastructure.

The most credible pathway forward is selective deployment: prioritizing green hydrogen in ammonia and fertilizer production, steel manufacturing, petroleum refining, maritime shipping fuels, and long-duration energy storage, while avoiding competition with electrification in passenger transport, residential heating, and light industry. Countries and companies following this targeted approach are most likely to achieve genuine emissions reductions rather than expensive dead ends.

Key Players

• NEOM Green Hydrogen Company (ACWA Power / Air Products) - Constructing the world's largest green hydrogen plant in Saudi Arabia, targeting 600 tonnes per day by 2026.
• Fortescue Energy - Australian mining giant pivoting to green hydrogen with $6.2 billion invested and operational facilities in Queensland.
• Plug Power - US hydrogen technology company operating the world's largest PEM electrolyzer factory and developing green hydrogen production hubs.
• Siemens Energy - Major electrolyzer manufacturer with gigawatt-scale production facilities in Berlin.
• ITM Power - UK-based PEM electrolyzer manufacturer supplying projects across Europe.
• Thyssenkrupp nucera - German electrolyzer manufacturer with alkaline technology deployed in large-scale industrial projects.
• European Hydrogen Bank - EU institution funding green hydrogen projects through competitive auctions.
• Hyundai Motor Group - Leading manufacturer of hydrogen fuel cell trucks and passenger vehicles with commercial fleets in multiple countries.

FAQ

Q: What is the difference between green, blue, and grey hydrogen? A: Grey hydrogen is produced from natural gas without carbon capture, generating significant CO2 emissions. Blue hydrogen adds carbon capture and storage to the reforming process, reducing but not eliminating emissions (typical capture rates are 85 to 95%). Green hydrogen uses renewable electricity to split water through electrolysis, producing zero direct emissions. The lifecycle carbon intensity of each pathway depends on methane leakage rates, capture efficiency, and the electricity grid mix.

Q: When will green hydrogen reach cost parity with grey hydrogen? A: Timelines vary by region. In locations with excellent renewable resources and supportive policy (such as the US with the 45V tax credit, or the Middle East with cheap solar), effective cost parity is achievable by 2027 to 2028. In Europe and East Asia, parity without subsidies is more likely by 2030 to 2032, assuming continued electrolyzer cost reductions and carbon prices above EUR 80 per tonne.

Q: Should I invest in hydrogen for my building's heating system? A: For the vast majority of buildings, heat pumps are a more efficient and cost-effective decarbonization pathway. Heat pumps deliver 3 to 4 units of heat per unit of electricity consumed, while hydrogen boilers convert roughly 85% of hydrogen's energy content to heat but require 2 to 3 times more primary energy to produce that hydrogen. Hydrogen blending in gas networks has been tested in the UK's HyDeploy project, but independent analyses suggest it offers minimal emissions reductions at high cost.

Q: Is there enough water for large-scale green hydrogen production? A: Electrolysis requires approximately 9 liters of purified water per kilogram of hydrogen. Scaling to 95 million tonnes annually would consume roughly 855 billion liters, about 0.02% of global freshwater withdrawals. Water availability is a local rather than global constraint: arid regions may need desalination (adding $0.01 to $0.02 per kilogram to production costs), while coastal or water-abundant regions face minimal water stress.

Q: What are the safety risks of hydrogen? A: Hydrogen is flammable with a wide ignition range (4 to 75% concentration in air) and burns with an invisible flame. However, it disperses rapidly due to its low density, reducing explosion risk in open environments. Industrial hydrogen handling has a strong safety record spanning decades, with established codes and standards (ISO, NFPA, CGA). New applications in transport and distributed energy require updated safety protocols but do not present fundamentally unmanageable risks.

Sources

• International Energy Agency. (2025). "Global Hydrogen Review 2025." https://www.iea.org/reports/global-hydrogen-review-2025
• Hydrogen Council and McKinsey & Company. (2025). "Hydrogen Insights 2025." https://hydrogencouncil.com/en/hydrogen-insights-2025/
• International Renewable Energy Agency. (2024). "Green Hydrogen for Industry: A Guide to Policy Making." https://www.irena.org/publications/2024/green-hydrogen-for-industry
• BloombergNEF. (2025). "Hydrogen Economy Outlook: 2025 Update." https://about.bnef.com/hydrogen/
• Ueckerdt, F. et al. (2024). "On the cost competitiveness of blue and green hydrogen." Joule, 8(1), 104-128.
• IRENA. (2025). "Renewable Capacity Statistics 2025." https://www.irena.org/publications/2025/renewable-capacity-statistics-2025
• Oil Change International. (2024). "Big Oil's Hydrogen Hype." https://priceofoil.org/hydrogen-hype
• European Commission. (2024). "European Hydrogen Bank: First Auction Results." https://ec.europa.eu/commission/presscorner/detail/en/ip_24_2333