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Sungrow, CRRC to provide tech for Kenya green NH3 plant
Sungrow, CRRC to provide tech for Kenya green NH3 plant
London, 24 March (Argus) — Chinese electrolyser manufacturers Sungrow Hydrogen and CRRC Zhuzhou have secured electrolyser supply contracts for the first phase of a geothermal-powered hydrogen and ammonia project in Olkaria, Kenya, developed by Chinese firm Kaishan Group. Kaishan signed a steam supply agreement with state utility KenGen in October 2025, under which KenGen will supply steam from existing geothermal wells for Kaishan to generate 165MW of electricity to power the electrolysers. Chinese firm Wuhuan Engineering is serving as engineering, procurement and construction contractor. Works on the site began in November 2025. Sungrow will supply 16 alkaline electrolysers rated at 1,000 Nm³/h each, while CRRC will provide eight units of the same rating, giving phase 1 a combined capacity of 24,000 Nm³/h, or around 120MW. This is sufficient to produce roughly 19,000 t/yr of hydrogen assuming continuous operation, which will be converted to the 100,000 t/yr of ammonia planned for phase 1. Kaishan plans to scale to 200,000 t/yr of ammonia at full build-out, with output processed into 480,000 t/yr of green fertilisers comprising 180,000 t/yr of urea and 300,000 t/yr of calcium ammonium nitrate. Kenya's government will offtake the fertiliser for distribution to local farmers to reduce import dependence. Total investment stands at around $800mn, with annual revenues projected at $220mn-250mn over a 25-year operating life, Kaishan said previously. Geothermal power offers a significant advantage for electrolytic hydrogen production, with capacity factors of around 90pc enabling near-continuous baseload operation without the intermittency or energy storage costs associated with solar and wind. Kenya's energy department estimates the country holds 10GW of geothermal potential, with only around 950MW of installed capacity to date. Chinese electrolyser makers have been increasing their equipment exports in recent months, supplying to projects in Europe, Middle East and Asia-Pacific. Sungrow delivered 160MW of alkaline electrolysers to Acme's green ammonia project in Oman , a 3MW containerised PEM system for Italy's MW-scale solar-to-hydrogen project , and a containerised alkaline system to a green hydrogen blending project in Brazil. By Chingis Idrissov Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
German government under pressure on climate target
German government under pressure on climate target
Berlin, 16 March (Argus) — Germany's greenhouse gas (GHG) emissions were almost unchanged last year, according to data released by federal environment office UBA on 14 March, putting pressure on the government ahead of its new climate action programme expected next week. GHG emissions fell by less than 1mn t of CO2 equivalent (CO2e), or 0.1pc, on the year in 2025 to 649mn t CO2e. Only the country's battered industry sector achieved meaningful cuts, as energy-intensive production declined further. Although this allowed Germany to meet its 2025 target under the country's climate action law — a 48pc cut in emissions against 1990 levels — the chances of the country reaching its 2030 climate target are lower than a year ago, UBA projections show. UBA expects Germany to post a 63pc emissions reduction in 2030, compared with 1990 levels, a 30mn t CO2e gap against the country's 65pc target. UBA also projects a gap of 100mn t CO2e in 2040, with reductions of 80pc against an 88pc target, assuming no change to emissions-cutting measures. The challenge to meet the 2030 target has become "bigger but not impossible", environment and climate minister Carsten Schneider said at the presentation of the data. Germany will need to reduce GHG emissions by an average of 42mn t CO2e/yr in 2026-30, Schneider said. Expected increases in heat pump and electric vehicle sales, and onshore wind power turbine deployment, are "beacons of hope", Schneider said. Germany's energy sector emissions fell by only 0.3pc last year, mainly owing to lower wind speeds, which reduced wind power and in turn increased gas-fired generation. Industrial emissions fell by 3.8pc, with UBA noting "slow progress" in the rollout of technologies such as electrification and green hydrogen. The country's transport sector posted an emissions rise of 1.5pc, on increasing traffic volume. The buildings sector was the worst performer, recording a 3.5pc rise in emissions as lower temperatures pushed up fossil fuel consumption for heating. Schneider underlined the urgency of investments to decarbonise buildings and transport, not the least to avoid "as far as possible" the purchase of carbon allowances from other EU member states under the bloc's Effort Sharing Regulation (ESR). UBA puts Germany's likely cumulative total gap under the ESR in 2021-30 at 255mn t CO2e. Emissions in the land use, land use change and forestry sector more than halved to 27mn t CO2e, mainly thanks to Germany's forests reverting to an emissions sink, absorbing 19mn t CO2e last year. Emissions in the agricultural sector were flat. The UBA projections were finalised in November and therefore do not reflect the latest developments in the oil and gas markets, or recent legislative proposals expected to curtail growth in renewable power and ease the continued use of oil and gas-based heating installations. Energy think-tank Agora Energiewende called for these legislative proposals to be revisited, as well as suggesting investments in "future-proof" infrastructure, additional tenders for onshore wind power and "clear" CO2 limits for car fleets. And environmental group DUH announced it will take further legal action — following its successful court case against the government in January — if next week's climate action programme "obviously" fails to close the gaps identified in UBA's projections. Germany's government-appointed council of experts on climate change has until mid-May to verify UBA's projection data. By Chloe Jardine Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
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.
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