Green Hydrogen Is Still a Vision. Blue Hydrogen Is Where the Industrial Gas Market Is Actually Moving

The Electrolyser Build-Out Is Running 18 Months Behind Every Published Forecast

The International Energy Agency's 2023 net zero scenario required 170 gigawatts of electrolysis capacity to be installed globally by 2030. Current installed capacity stands at approximately 1.4 gigawatts. The gap is not primarily a technology problem , proton exchange membrane and alkaline electrolysers are commercially mature at module scale. The constraints are grid connection queues for renewable power, electrolyser component supply chains concentrated in Chinese manufacturing, and the absence of hydrogen offtake contracts at prices that justify the capital expenditure required to build at gigawatt scale. ThyssenKrupp Nucera, Nel Hydrogen, and ITM Power have all revised their near-term revenue guidance downward in 2025 as project final investment decisions were deferred by customers waiting for subsidy certainty under the EU Hydrogen Bank and the US IRA.

The commercial consequence of the green hydrogen delay is straightforward: industrial demand for hydrogen is not waiting. Refinery hydroprocessing, ammonia synthesis, methanol production, and the emerging direct reduced iron steelmaking pathway all require hydrogen now, and the volumes required for any meaningful steel or ammonia decarbonisation are orders of magnitude larger than current green hydrogen supply. Air Liquide, Linde, and Air Products have responded to this gap not by accelerating electrolyser investment but by scaling blue hydrogen projects , steam methane reforming with carbon capture and storage , where the gas resource, carbon capture infrastructure, and industrial offtake can be co-located in existing industrial clusters.

Carbon Capture Integration Is the Competitive Differentiator in Industrial Gas Contracts Today

Air Products' NEOM green hydrogen project in Saudi Arabia and its Louisiana blue hydrogen complex represent opposite ends of the industrial gas sector's hydrogen strategy. The NEOM project has faced repeated timeline revisions and is not expected to reach full production until after 2027. The Louisiana blue hydrogen facility, co-developed with carbon capture infrastructure targeting permanent geological storage in saline aquifers under the Gulf of Mexico, reached positive FID in early 2025. The pattern is consistent with the broader sector: blue projects with integrated CCS are reaching financial close while green projects are extending feasibility timelines.

The economics explain the behaviour. Blue hydrogen production cost with CCS currently runs at USD 1.5-to-2.5 per kilogram depending on natural gas input price, carbon credit value, and CCS transport and storage cost. Green hydrogen is currently producing at USD 4-to-7 per kilogram in most markets, with optimistic projections reaching below USD 2 per kilogram by 2030 only under specific conditions of cheap renewable electricity and high electrolyser utilisation rates. The USD 2-to-5 per kilogram spread between blue and green is simply too large for industrial offtakers to absorb without policy mandates that specify green hydrogen by certificate of origin, and the markets with those mandates cover only a fraction of total industrial hydrogen demand.

Ammonia Is the Bridge Molecule That Industrial Gas Companies Are Betting On

Ammonia's role as a hydrogen carrier has moved from research curiosity to active commercial infrastructure investment. CF Industries, Yara International, and OCI are all developing blue ammonia production capacity with offtake agreements anchored to Japanese and South Korean utility customers who have committed to ammonia co-firing in coal power plants as a near-term decarbonisation pathway. Japan's ammonia co-firing programme under METI policy support is targeting 20 percent co-firing at selected coal plants by 2030, creating a contracted demand pull for blue ammonia that currently has no equivalent in the green hydrogen supply chain.

The industrial gas majors are positioning ammonia infrastructure as a bridging asset. Linde's partnership with ADNOC on blue ammonia production in Abu Dhabi, and Air Liquide's offtake agreements with Japanese utilities through its hydrogen derivatives business, reflect a commercial strategy of supplying the hydrogen economy through existing molecular derivatives rather than pure hydrogen transport. Ammonia crackers , the reverse process of splitting ammonia back into hydrogen at the point of use , are being developed by companies including Casale, ThyssenKrupp, and KBR to enable ammonia to serve as a practical hydrogen transport medium for end-users who cannot accept ammonia directly. This infrastructure layer is where industrial gas capital is concentrating in 2026.

Cryogenic and Specialty Gas Demand Is Growing Independent of the Hydrogen Debate

Beyond hydrogen, the industrial gas sector is experiencing strong demand growth in cryogenic gases driven by semiconductor fabrication, medical oxygen infrastructure expansion in emerging markets, and the liquid nitrogen requirements of direct air capture facilities. TSMC's expansion in Arizona and the broader US CHIPS Act-funded fab build-out requires ultrapure nitrogen, argon, and specialty fluorine-based process gases in volumes that are stretching Air Products and Linde's on-site production capacity in the US Southwest. Messer Group and Matheson are both investing in new air separation unit capacity in proximity to planned semiconductor fabrication sites, with long-term supply agreements structured around fab production milestones.

Helium supply is the most acute constraint in the specialty gas market. Following the partial loss of BLM Federal Helium Reserve supply after 2024, the market is increasingly dependent on Qatar, Russia, and new sources in Tanzania and Algeria. The US government's strategic helium reserve draw-down policy has structurally reduced a buffer that previously dampened price volatility, and MRI machine manufacturers, semiconductor lithography equipment producers, and fibre optic cable manufacturers are all facing supply commitments that require 12-to-18 month advance contracting. For Linde and Air Liquide, helium supply security through long-term source agreements is now a competitive differentiator in specialty gas contracts with premium technical customers.

Carbon Credits and Voluntary Markets Are Reshaping Blue Hydrogen Project Economics

The voluntary carbon market's treatment of blue hydrogen CCS credits has become a significant variable in project financial models. Under the Science Based Targets initiative and Gold Standard frameworks, blue hydrogen CCS can generate carbon credits only to the extent that captured CO2 is permanently sequestered and the capture rate exceeds 90 percent. Projects that achieve 95-plus percent capture with verified geological sequestration are generating credits that trade at meaningful premiums in voluntary carbon markets, directly subsidising the cost of the CCS component and improving the economics of blue hydrogen relative to grey (unabated SMR) hydrogen production. Air Products' Louisiana facility is structured to maximise carbon credit generation as a parallel revenue stream to the industrial hydrogen supply contract, and this dual-revenue architecture has become the template for blue hydrogen project financing in the US IRA environment.

The IRA's Section 45V clean hydrogen production tax credit, which pays up to USD 3 per kilogram for hydrogen produced with a lifecycle carbon intensity below 0.45 kilograms CO2 per kilogram H2, has created a specific race among industrial gas producers to achieve the most rigorous low-carbon certification for blue hydrogen projects. The tax credit's lifecycle accounting methodology, administered through the Department of Energy's GREET model, treats methane leakage in the natural gas supply chain as a key variable , a detail that has driven Air Liquide, Linde, and Air Products to negotiate direct pipe-sourced natural gas supply agreements with defined methane measurement protocols, rather than accepting standard pipeline gas with undefined upstream emissions. This compliance-driven supply chain restructuring is itself generating new commercial activity in methane monitoring technology and gas supply certification services.

Top 10 Companies in the Global Industrial Gases Market

1. Linde , World's largest industrial gas company by revenue; active across hydrogen, cryogenics, and electronics gases with global on-site supply infrastructure
2. Air Liquide , French industrial gas major with extensive hydrogen pipeline networks and blue hydrogen CCS project partnerships in the US and Middle East
3. Air Products , US industrial gas company with the world's largest green hydrogen project (NEOM) and multiple blue hydrogen CCS facilities
4. Taiyo Nippon Sanso (Matheson) , Japanese industrial gas group with aggressive semiconductor gas supply expansion in the US through its Matheson subsidiary
5. Messer Group , German industrial gas specialist with US and European ASU capacity expansion near semiconductor fabrication cluster sites
6. CF Industries , US nitrogen fertiliser and blue ammonia producer developing low-carbon ammonia for Japanese utility co-firing offtake
7. Yara International , Norwegian ammonia and fertiliser producer transitioning toward blue and green ammonia through its Yara Clean Ammonia division
8. ThyssenKrupp Nucera , Electrolyser manufacturer and ammonia cracker developer supplying both green hydrogen production and ammonia decomposition systems
9. Helium One Global , Tanzania-based primary helium explorer developing the Rukwa Basin as a new non-Russian, non-Qatari helium supply source
10. OCI Global , Dutch nitrogen chemicals company with blue and green ammonia capacity development in the US, Netherlands, and Middle East