Overview
Hydrogen is an increasingly important piece in the decarbonisation puzzle. Industrial players are seeking ways to take carbon emissions out of their hydrogen production processes, while green hydrogen producers see the gas as a viable outright alternative to hydrocarbons.
Future production routes range from methane reformation with carbon capture to pyrolysis, waste gasification and electrolysis, powered by renewable energy or fossil fuels. Combinations of processes and energy being used to produce hydrogen presents existing users of industrial heat and key chemicals a challenging landscape to navigate.
The Argus Hydrogen and Future Fuels service has been designed to provide industrial power, chemicals and energy users with crucial information to help them make well informed decisions. It covers the upstream for projects, midstream for transportation and storage, and downstream for ammonia and methanol. It also covers the latest technological developments and policy news on hydrogen from across the globe.
Latest hydrogen news
Browse the latest market moving news on the global hydrogen industry.
UK's grid, offtake risks threaten H2 FIDs: Utilities
UK's grid, offtake risks threaten H2 FIDs: Utilities
London, 13 March (Argus) — Grid connection delays, difficulty securing long-term hydrogen offtake deals and challenges sourcing compliant low-carbon power are the main barriers to UK renewable hydrogen projects reaching final investment decisions (FIDs), utilities RWE Generation and Statkraft said at the Hydrogen UK conference this week. RWE is developing large-scale renewable hydrogen projects in Germany , in the Netherlands and in the UK, leveraging its sizeable renewable portfolio in northwest Europe. RWE's UK green hydrogen schemes include a 100MW electrolyser at Pembroke and a 100MW plant at Grangemouth — the latter reduced from 200MW on weaker demand expectations . Both are shortlisted in the UK's second hydrogen allocation round (HAR2). RWE also plans a potential HAR3 bid with its Liverpool Bay project for connection to the HyNet network . HyNet partner Progressive Energy's chief executive Chris Manson Whitton said it would be a "three digit megawatt" electrolyser. But Claire Woodward, RWE's head of UK hydrogen project development, said grid connection dates are "very uncertain" and any timeline slips could affect HAR2 eligibility. Offtaker risk is the biggest hurdle, she said. A lack of hydrogen pipelines forces 15-year contracts with single local buyers, creating significant risks for producers, customers and financiers. Combined with delays to the HAR2 award decision , these factors make securing the board's FID approval difficult, she said. State-owned Low Carbon Contracts Company (LCCC) head of hydrogen Emma Bezuidenhout said HAR1 projects also face delays between signing subsidy contracts and FID because of offtake challenges. Electricity sourcing further complicates development. Statkraft's vice president of origination Duncan Dale said reliance on a single co-located renewable asset can leave electrolysers idle for too long, undermining profitability. Using grid electricity at uncertain carbon intensity risks non-compliance with the UK's low carbon hydrogen standard (LCHS) and HAR rules, Dale said, and hidden electrical infrastructure costs also offset any savings from co-located designs. Dale said developers need utility partners with "massive and diverse" renewable portfolios to stay profitable, limit spot market exposure and maintain LCHS compliance. Even with a 5:1 wind farm-to-electrolyser capacity ratio, he said, electrolysers would still use grid power 33pc of the time at uncertain price and carbon intensity. Dale said a 15-year fixed price power purchase agreement (PPA) with a creditworthy supplier is essential. A £20/MWh price increase over 15 years for 1 TWh/yr equates to £300mn in losses — "peanuts" compared with potential geopolitical driven swings, Dale said. Electricity accounts for 70–80pc of levelised hydrogen production costs, making cost control critical. By Chingis Idrissov Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
Gas TSOs urge uniform EU standards, H2 pipes derisking
Gas TSOs urge uniform EU standards, H2 pipes derisking
Prague, 12 March (Argus) — Uniform standards and more clarity on financing mechanisms for pipelines are needed to pave the way for future cross-border hydrogen flows in Europe, according to gas transmission system operators (TSOs). There are no major technical challenges for development of national and cross-border hydrogen networks, but many regulatory questions have yet to be resolved, TSO representatives told the Hydrogen Days 2026 event in Prague on 11 March. Standards for hydrogen quality and pressure must be set on an EU level soon to help pipeline operators with their planning, said Czech TSO Net4Gas' head of hydrogen readiness, Lenka Krausova. It also needs to be clear how border flows are measured, Krausova said. TSOs that are already building national hydrogen networks are developing national solutions at the moment, but eventually rules on quality, pressure and balancing must be covered by EU-wide regimes to facilitate cross-border flows, said Helmie Botter, head of hydrogen transport at Dutch state-owned Gasunie. Ennoh, the association of hydrogen network operators, will have a key role to play in setting the necessary standards. The European Commission must set a list of priorities for network codes which Ennoh will then address with its members, the group's director Abel Enriquez said. Besides quality and pressure standards, Enriquez also highlighted the importance of transparency on available capacities and future hydrogen flows. Ennoh is planning to launch a transparency platform in October, he said. Another pressing concern is development of a European model for derisking financing of hydrogen networks, Enriquez said. The hydrogen market is still in a nascent stage and utilisation of future networks is still uncertain, especially in the initial phases, which creates investment risks for TSOs, panellists agreed. Ennoh launched a consultation on potential derisking options on 10 March. In a draft report, the group reviewed numerous derisking options, concluding that "no single mechanism is sufficient to address the scale and nature of the challenge". Ennoh has proposed a system that centres around a tariff approach based on inter-temporal cost allocation (ICA) and an amortisation account, combined with a European budget-backed guarantee as a safety mechanism if networks remain underutilised. This would be similar to the approach taken by Germany for its network. An alternative option would be long-term capacity bookings through a European special purpose vehicle, Ennoh said. "In the absence of a European-level de-risking framework, there is a material risk that cross-border hydrogen infrastructure will not develop at the pace required to meet Union climate and energy objectives," the group said. Gasunie's Botter said a derisking instrument on an EU-level would be a "gamechanger" for driving infrastructure projects forward. Gasunie has so far developed around 100km of its planned hydrogen network , with 70km of repurposed gas pipelines and a new 30km connection, Botter said. She expects first cross-border connections with Germany to become available by the end of 2029 or in 2030. Germany wants the EU to provide more direct funding for cross-border hydrogen infrastructure, said Gunther Grathwohl, head of division for international hydrogen ramp-up at Germany's economy and energy ministry. Berlin is pushing for this to be introduced as part of the European Grids Package and is hoping for other member states to back these plans, Grathwohl said. By Stefan Krumpelmann Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
China’s GuofuHee widens 2025 loss on weak H2 demand
China’s GuofuHee widens 2025 loss on weak H2 demand
London, 9 March (Argus) — Chinese hydrogen equipment supplier Jiangsu Guofu Hydrogen Energy Equipment (GuofuHee) expects its losses for the year ending 31 December 2025 to widen to 250mn-390mn yuan ($36.2mn-56.5mn), an increase of 18.9pc-85.5pc from 2024. The Hong Kong-listed firm issued a warning to its investors, saying full-year 2025 results will be hit by a "slowdown of overall market demand" in China, echoing a similar warning from a year earlier. Government policies have not yet translated into the level of market activity the company had expected, and hydrogen end-use applications are taking longer to mature, it said. The firm also reported higher credit impairment and asset impairment losses, further widening losses. The forecast is based on preliminary unaudited figures and may change when GuofuHee publishes its annual results by the end of March. GuofuHee's warning highlights challenges in China's increasingly crowded and competitive electrolyser market , where firms have been bidding aggressively with lower prices in hydrogen project tenders. GuofuHee produces alkaline and proton exchange membrane electrolysers, as well as purification units, liquefaction systems, refuelling equipment and natural-gas-to-hydrogen power systems. The company is among the largest electrolyser makers globally. It expanded capacity its alkaline electrolyser plant in Zhangjiagang, Jiangsu province, from 1GW/yr to 3.5GW/yr at the end of 2024. It is also pursuing overseas growth, with plans to commission a 250MW/yr alkaline electrolyser plant in Germany this year. Much of this 3.5 GW/yr alkaline capacity may be under-utilised, similar to other electrolyser makers globally . Despite these pressures, GuofuHee maintains that China's hydrogen sector remains at an "initial stage of commercialisation" and still shows "obvious policy-driven characteristics". This comes even as the country hosts some of the world's largest renewable hydrogen and derivatives projects, with Chinese firms generally executing projects at a faster pace than others globally. The firm is also seeking more overseas business, with plans to supply electrolysers to projects in Malaysia , Saudi Arabia and other international markets. Guofu is also exploring other manufacturing partnerships in India and South Africa . By Chingis Idrissov Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
CIP, Hy2Gen cancel renewable ammonia project in Norway
CIP, Hy2Gen cancel renewable ammonia project in Norway
Paris, 9 March (Argus) — Danish renewables developer Copenhagen Infrastructure Partners (CIP) and German hydrogen company Hy2Gen have cancelled a 240MW renewable hydrogen and ammonia project in Norway. The Iverson eFuels project, planned for Sauda, in southwest Norway, lost its grid access. Norwegian power system operator Statnett decided in late 2025 to withdraw a previously allocated 270MW of electricity capacity because project development was more than two years delayed compared to original plans, Iverson said. When the Iverson project was announced in 2022 , the companies expected construction to begin in 2024 and operations to start in 2027, targeting production of 200,000 t/yr of renewable ammonia. Statnett said that new capacity could be available only once the grid is upgraded, which is expected in 2033-2035. "Such an uncertain situation" about securing grid capacity "is not compatible with further development of the project," Iverson said. The project partners will assess possible development of a data centre project at the Sauda site "so that the work and resources invested in the Iverson project can be utilised to create new activity", they said. By Pamela Machado Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
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