Hydrogen
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 Cadent delays HyNet H2 network for policy clarity
UK's Cadent delays HyNet H2 network for policy clarity
London, 28 November (Argus) — UK gas network operator Cadent has halted its planning application for the HyNet North West hydrogen pipeline, citing uncertainty about government timelines and subsidy allocation under the hydrogen transport business model (HTBM), which will not be finalised until spring 2026. Cadent had aimed to submit a development consent order (DCO) by end of 2025 after public consultations and front-end engineering design work, targeting a final investment decision (FID) in 2026 if government support materialises. But the firm said it will pause the DCO process, although environmental surveys and routing assessments will continue. Cadent said the government has confirmed it will finalise the HTBM and start the process for one hydrogen pipeline in spring 2026. The government said in July that the first regional hydrogen transport and storage network should start up by 2031. The operator said in June it plans to have the network operational in the early 2030s, probably to align with Essar Energy Transition's plans for its Stanlow site, and carry hydrogen from there. The plant's second phase will supply regional customers, while initial output will serve Essar's refinery. UK operators like Cadent are also waiting for clarity on hydrogen blending into existing gas grids as a fallback when industrial demand is low. Cadent has submitted evidence supporting up to 20pc blending in pilots. The delay adds uncertainty to the project, which may compete for HTBM support with other developers, potentially pushing back FID. Cadent did not respond to requests for comment. The HTBM is designed to make early-stage pipeline projects viable by guaranteeing returns. It combines a regulated asset base model — where operators earn a capped return on infrastructure costs — with government subsidies to cover revenue shortfalls while demand builds up. This gives investors long-term certainty needed for FID. HyNet's 125km pipeline network would link Stanlow to industrial users and blending points. The CO2 element of HyNet is progressing, with Eni reaching financial close on its storage site and Eni and Essar securing DCO approval for the CO2 pipeline. By Chingis Idrissov Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
Pattern Energy pauses Newfoundland green H2 plan
Pattern Energy pauses Newfoundland green H2 plan
Houston, 26 November (Argus) — US clean energy developer Pattern Energy has suspended plans to build a renewable hydrogen and ammonia facility in Newfoundland and will instead move forward with a standalone wind farm. Pattern's Canadian subsidiary, Argentia Renewable Wind LP, withdrew an environmental-assessment request from the province's Department of Environment, Conservation and Climate Change for a project that would have harnessed wind energy to produce hydrogen and green fuels like ammonia for export to northwest Europe. Pattern will submit a new request in the coming weeks for a wind farm to provide power to the local grid, the company said in an email. "We are preparing a new Environmental Assessment (EA) that reflects a phased approach," said Frank Davis, head of Canada for Pattern Energy in a statement to Argus . "The revised EA outlines a wind-generation project designed to deliver energy to Newfoundland & Labrador." Six companies have received permission from the province to pursue wind power-to-hydrogen projects to export either hydrogen or ammonia to buyers in Europe. Project time lines have slipped or stalled as that demand has failed to materialize as expected, sparking speculation that developers could pivot to projects providing only wind power. Pattern did not comment on what factors lead to its decision to withdraw the hydrogen project for consideration. Pattern originally conceived building a 300MW wind farm to power the production of hydrogen and green ammonia in partnership with the Port of Argentia. Earlier this year, the Port signed a letter of intent with the Hamburg Port Authority to collaborate on a so-called "hydrogen export/import corridor" between Newfoundland and Germany. The facility would have included storage and distribution infrastructure for an initial capital investment of around C$1.4bn, according to company documents. The company is now looking to build 150MW of wind power as a first phase and said "potential future phases" involve hydrogen and green fuels. In July, utility Newfoundland and Labrador Hydro issued a request for expressions of interest to supply energy and/or capacity to the province's Island Interconnected System, seeking 150mw of firm capacity and up to 500GWh of firm energy. By Jasmina Kelemen Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
Q&A: Marine decarbonisation to continue despite delay
Q&A: Marine decarbonisation to continue despite delay
Sao Paulo, 24 November (Argus) — The maritime sector is staying on course towards decarbonisation, with marine biofuels and LNG gaining traction in the short term, despite the IMO postponing its net-zero framework vote until October 2026, DNV global decarbonisation director Jason Stefanatos said. No single fuel is likely to be adopted at scale in the medium to long term, and alternative marine fuels will coexist as part of the path to net zero, he said. Edited highlights follow. IMO delegates have postponed a vote on the net-zero framework until next year. What's your view on the delay, and how might it impact the adoption of alternative bunker fuels? The postponement of the IMO net-zero framework highlights the need for greater clarity on its practical implementation. But while the delay creates some uncertainty, the industry's decarbonisation targets remain unchanged. DNV's October 2025 AFI data confirms that the industry's commitment to alternative fuels remains strong Which fuels are the leading trend in maritime decarbonisation in the short and long term? In the short term, both LNG and biofuels are leading trends in maritime decarbonisation because of LNG bunkering infrastructure and because biofuels are drop-in. Over the longer term, the transition will diversify, adding more fuels in the mix, with methanol, ammonia, hydrogen and e-fuels expected to play roles as technology, supply and regulatory frameworks mature. There is no trend in the long term. The most suitable fuel and technology will be determined by each operator's specific fleet characteristics, operational requirements, overall commercial objectives, as well as global and regional geopolitical decisions and developments. With the energy transition underway in the maritime sector, is ethanol an option for mid- and long-term decarbonisation? Ethanol is technically feasible as a marine fuel, and has gained more popularity in the past months due to technical developments by engine makers and developments on the supply side. Although the vast majority today does not come from sustainable biomass, it is a promising new fuel that could play a role in the future. Its similarities with methanol enable methanol-fuelled vessels to easily switch to ethanol if needed, providing further fuel flexibility, which is important during high uncertainty times. E-fuels have been identified as a potential net-zero fuel. How do you see their development as a marine fuel, considering they are not currently available at commercial scale? E-fuels are presented as a long-term solution for maritime decarbonisation, but their commercial availability and cost competitiveness remain challenges for widespread adoption. Demand is expected to grow as regulatory requirements tighten, but supply will depend on large-scale investments in renewable energy and production capacity. Ammonia is a possible alternative fuel for the future, but barriers to its adoption remain, DNV said in a recent publication. Why does it make sense to invest in ammonia as a bunker fuel when other fuels are more established and safer? Ammonia has benefits and barriers on its adoption. On the benefits side, ammonia is a fuel without carbon content, can act as a hydrogen carrier, and has some basic infrastructure and technology in place, as there are already vessels operating with ammonia. On the other hand, safety and technical issues will require a lot of industry effort to be overcome. The FuelEU Maritime regulation introduced a 2pc reduction target for GHG emissions from vessels in 2025. Individual EU countries are implementing their own RED III regulations this year. Are these emission policies driving demand for alternative fuels, or should the EU consider tightening its restrictions? And what do these regulations mean for the wider global market? These regulations are drivers for alternative fuel demand in shipping and have contributed to accelerating investment in low-GHG fuels and technologies. However, the global impact will depend on how IMO regulations will be agreed and defined by the delegates. Some uncertainty remains as further regional regulations could lead to uneven competition and increased complexity for international operators. By Natália Coelho and Gabriel Tassi Lara Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
Q&A: Hiringa aims to grow Australia’s green NH3 market
Q&A: Hiringa aims to grow Australia’s green NH3 market
Sydney, 21 November (Argus) — New Zealand-based hydrogen developer Hiringa Energy has begun construction of its 15MW Good Earth Green Hydrogen and Ammonia (GEGHA) project near Moree in northwest New South Wales (NSW). Argus spoke with the firm's commercial and business development lead Jack Rickers on the sidelines of the Asia-Pacific Hydrogen Summit in Sydney about the company's future plans. Can you talk us through the GEGHA project and what stage it is at? We're aiming to be operational in the first quarter of 2027, [joint venture partner] Sundown Pastoral saw a similar project that we were doing over in New Zealand, where we working with a fertilizer manufacturer to decarbonise urea feedstocks. We built a 41MWh BESS system at GEGHA providing affordable, reliable supply of power into the electrolysers to make hydrogen for anhydrous ammonia supply. What is the opportunity for expanding this project into agricultural markets in Australia? Anhydrous ammonia isn't a big market on the east coast of Australia, a lot of growers used to use anhydrous but shifted due to supply chain security. What we're doing is transferring that supply chain to provide price competitiveness against fossil fuel products. More importantly for a lot of growers though is the security and the availability of that fertiliser input. What are the other uses for the hydrogen GEGHA produces? Some of the hydrogen is going to displace diesel in irrigation pumping as well as in other mobile and static on-farm equipment. Fuel and fertilizer produce the greatest emissions but also form the highest costs for these farming operations, so via GEGHA we're looking at low-carbon alternatives. What is the growth potential for green ammonia in Australia? If you look at the direct-use ammonia opportunity it's not large, I think it's averaged about 40,000-50,000 t/yr over the last 10 years. GEGHA is 4,500 t/yr but we've got a couple of other expansion projects underway. We got quite a significant [A$35.8mn ($23mn)] government grant for GEHGA, but what we're working on now is improving the economy of scale, by doing it at about five times the volume we don't think that we need the government to achieve competitive pricing of those products into the market. We've got two other projects planned in NSW, both at the 20,000 t/yr scale, meeting the market's anhydrous demand. The broader nitrogen market, though, is really our target market — which is primarily the 2mn t/yr urea market in Australia's eastern states. Farmers prefer that granular or liquid form but we're having a look at other fertilizer derivatives using anhydrous ammonia as feedstock. What model does Hiringa see as ideal for growing its anhydrous ammonia footprint? We're looking at when does it become expensive for traditional fertilizers and how does that help us compete? That's around what that delivered price is so we're producing hub and spoke projects — rather than going giga-scale then trucking [fertilizer] 500km inland, we're doing it within those regions where people are going to use it, so we don't have that transport cost. We're looking at another 20,000 t/yr plant in the [NSW] Gwydir region, a 20,000 t/yr plant in the Riverina and probably a third plant in the Darling Downs of Queensland. Why have you targeted cotton-growing regions so far? Is it a crop that supports the margins involved? Cotton uses about 75pc of Australia's direct-use anhydrous supply, it's the largest direct market for us to address. But as we start to move from that 5,000 t/yr to 20,000 t/yr scale we're looking at what other cropping products make sense, how do we produce a product suitable for winter [grains] cropping to smooth that seasonality curve of [summer-grown] cotton. By Tom Major Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
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