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UK parliament approves SAF mandate from 2025

  • Market: Biofuels, E-fuels, Electricity, Hydrogen, Oil products
  • 06/11/24

The UK parliament has approved the proposed sustainable aviation fuel (SAF) mandate that will come into effect on 1 January, 2025.

Obligated suppliers will have to deliver a 2pc share of SAF in 2025, increasing to 10pc in 2030, 15pc in 2035 and 22pc in 2040. The obligation will remain at 22pc from 2040 "until there is greater certainty regarding SAF supply".

The obligation arises at the point at which a supplier's jet fuel can be supplied only to UK aviation.

Hydrotreated esters and fatty acids (HEFA) SAF can be used to meet 100pc of SAF demand in 2025 and 2026, but will be capped at 71pc in 2030 and 35pc in 2040. An obligation for Power-to-Liquid (PtL) SAF will be introduced from 2028 at 0.2pc of total jet fuel demand, rising to 0.5pc in 2030 and 3.5pc in 2040.

Buy-out mechanisms will be set at the equivalent of £4.70/l ($6.10/l) and £5.00/l ($6.50/l) for the main and PtL obligations, respectively.

"It is projected that, between 2025 and 2040, the SAF mandate could deliver up to 25mn t of SAF, securing a saving of up to 54mn t of carbon dioxide", said transport minister John Hendy.

The UK confirmed on 17 July it will introduce the Sustainable Aviation Fuel (Revenue Support Mechanism) bill to support SAF production. The government previously said it aims to introduce the mechanism, which will be industry funded, by the end of 2026.

"Together with the SAF mandate, [the mechanism] will give the investment community confidence to invest in these novel and innovative technologies", Hendy said.


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20/03/25

TotalEnergies delays, cuts size of Grandpuits HVO

TotalEnergies delays, cuts size of Grandpuits HVO

Barcelona, 20 March (Argus) — TotalEnergies is delaying the start up of its Grandpuits hydrotreated vegetable oil (HVO) plant, and is planning to reduce the plant's proposed capacity. TotalEnergies confirmed the planned 400,000 t/yr HVO and HVO jet fuel (SAF) plant, near Paris, will not start in 2025 as previously outlined. Instead, a first phase of 210,000t of SAF output is slated to begin operations "early in 2026." TotalEnergies said there will then be a second phase of 75,000t, which will start at an unspecified point in 2027, giving 285,000 t/yr. If all production is SAF this would be equivalent to around 6,155 b/d. The CGT union said its members at Grandpuits downed tools for 24 hours yesterday, 19 March, as a result of the company's announcement. Workers say they have been promised a meeting with management in mid-April, and there does not appear to be industrial action at the site today. TotalEnergies halted crude distillation at the 93,000 b/d Grandpuits four years ago . The transformation includes a 10,000 t/yr plastics recycling unit. It said 1,200 workers are on site to undertake the conversion and this will result in 250 full time posts on completion. This is consistent with previous plans . The delay and reduction in size at Grandpuits does appear to confound targets for TotalEnergies' HVO and SAF output previously laid out by chief executive Patrick Pouyanne . The company operates a 500,000 t/yr HVO and SAF plant at La Mede, near the port of Fos-Lavera. A Grandpuits worker said management has indicated the company will look to purchase HVO and SAF, in order to honour contractual obligations. By Adam Porter Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Canberra backs Li battery projects in Western Australia


20/03/25
News
20/03/25

Canberra backs Li battery projects in Western Australia

Sydney, 20 March (Argus) — Australia's federal government will partly underwrite four lithium-ion battery projects in Western Australia (WA), boosting the state's energy storage capacity by 2.6GWh from late 2027. Canberra is supporting the projects through its Capacity Investment Scheme (CIS), which sets a revenue floor on big battery projects for up to 15 years. The government has not revealed the specific revenue floors linked to the newly underwritten projects. Australian renewable energy developer PGS Energy will build the largest of the four newly-underwritten batteries, a 1.2GWh energy storage system in Marradong. The company's Marradong battery will be co-located with a solar farm and connected to WA's South West Interconnected System (Swis), a grid stretching across its most populous regions, once it becomes operational. French energy producer Neoen is also developing a 615MWh project just outside Perth, under the scheme. The company has been building large batteries across Australia, with public support, for multiple years. Its Collie Battery Energy Storage System is connected to Swis, and has been storing and discharging 877MWh of energy since October 2024. The two other batteries underwritten on 20 March are smaller, with a combined capacity of 780MWh, and located in rural parts of the state. The Australian government's latest funding announcement comes just months after it on 11 December 2024 underwrote eight other Australian battery projects capable of storing 3.6GWh of power under the CIS. Those projects were scattered across the country, covering three states but excluding WA. Canberra will also underwrite another set of batteries, with a combined capacity of 16GWh, in September. Over 100 projects, with a combined capacity of 135GWh, have applied to be part of CIS' September funding round. By Avinash Govind Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Australia must rethink gas strategy: Grattan


20/03/25
News
20/03/25

Australia must rethink gas strategy: Grattan

Sydney, 20 March (Argus) — Grattan's Orange Book 2025: Policy priorities for the federal government report suggests redesigning Canberra's future gas strategy, coordinating a shift away from gas for households and some industries while changing market control mechanisms. Australia's next federal government must act to address a shortfall of gas in the country's southeastern states by creating a demand response mechanism for the national gas market and bringing together stakeholders to permit initial LNG imports in mid-2026, according to Grattan. Australia has always been both an exporter and importer of LPG, proving it is possible to build infrastructure to ship gas to the nation's south for the next 3-4 years in line with expected shortfalls, director of Grattan's energy program Tony Wood told a Sydney forum on 19 March. Building or expanding gas pipelines would be expensive and inefficient as the nation decarbonises, Wood said, with less gas forecast to be used as Australia targets net zero emissions by 2050. Canberra should institute a working group involving producers, users, traders, terminal owners, governments and the Australian Competition and Consumer Commission — which reports on market supply — to achieve seasonal imports of LNG in winter months, according to the Grattan report. A rule change to create a demand response mechanism akin to that under national electricity market rules would assist in meeting small shortfalls, such as during severe weather or unexpected supply outages. Demand is expected to rise on the back the closure of coal-fired power stations in the 2030s, according to Canberra's future gas strategy released in 2024. Gas-fired power demand may double in the decade to 2043 because of the need to support a solar and wind-heavy grid. This requires a reworking of the future gas strategy to specify plans to reduce demand and clarify future gas requirements outside of power generation, Grattan's report said. Assistance for households and industries to electrify processes is also needed, together with optimising infrastructure to ensure residual users in power generation and industry can access gas supply. The main controls on east coast gas grids, the Australian Domestic Gas Security Mechanism (ADGSM) and code of conduct , should be revised to allow for interstate transfers of gas, Grattan said, likely from Queensland's Gladstone-based LNG projects to the southern states. The code of conduct, which mandates an A$12/GJ ($8/GJ) price on domestic gas, came into effect in 2023 amid booming global gas prices but must be reviewed in 2025. Australia's energy and climate change ministerial council met on 14 March but declined to decide on expanding the Australian Energy Market Operator's powers, to enable it to address the gas shortage possibly through underwriting LNG import terminals. More analysis will be commissioned ahead of a decision at the next meeting in mid-2025. 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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Swedish wind output structurally shifts Nordic hydro


19/03/25
News
19/03/25

Swedish wind output structurally shifts Nordic hydro

London, 19 March (Argus) — Higher Swedish wind output is a structural supply shift that could support Norwegian hydro stocks over the long term, as recent record hydro reserves come despite below-average rainfall between October 2024 and February 2025. Combined Nordic hydropower reserves have held a surplus to the 10-year maximum for eight of the first 10 weeks of 2025, peaking at seven percentage points in week 10, as Norwegian hydro reserves unexpectedly increased from a week earlier. Reserves across Finland, Norway and Sweden closed week 10 at 55.6pc of capacity, seven percentage points above any other week in the previous 10 years and 5.1 percentage points higher than in 2008, the next highest year. Hydro production in Norway fell on the year in 2024, dropping to an average of 12.1GW, down from 12.2GW in 2023 and around 7pc below the five-year average of 12.9pc. Tighter hydro conditions in the first half of the year weighed on generation. Still, in the final six months of 2024, hydro reservoir output also fell on the year, dropping by 4pc to an average of 11.4GW, down from 11.9GW. That is despite combined Nordic reserves last year holding an average stock surplus of 5.2 percentage points to 2023 between weeks 34 and 52. At the same time, Swedish wind output increased to an average of 4.6GW last year, up by 18pc on the year from 3.9GW a year earlier and ending last year around 34pc higher than the five-year average. Higher wind generation weighs significantly on regional day-ahead prices and discourages hydro production by lowering the spot below the perceived water value of stored hydropower capacity. Rising wind capacity and its effect on the power mix is particularly notable during the first and fourth winter quarters, with generally the highest prices, with Swedish wind output averaging 5.8GW last year between January and March and October and December, up by 22pc from the equivalent periods in 2022. That displacement represents a structural supply shift in the Nordic power market that can support hydro reserves beyond rain and temperature outlook patterns going forward and during below-average precipitation periods, as the call for hydro production falls in hours when wind output is highest that — before significant wind capacity additions in Sweden — were routine output hours. Furthermore, higher run-of-river generation last year, up by 8pc in 2024 compared with a year earlier to an average of 3.4GW, captures the higher stock feed-in and water volumes that supported Nordic reservoirs in 2024 leading into 2025 and emphasises that, like wind output, run-of-river, which is generally not dispatchable undermines the regional spot price and reduces the call for reservoir hydro output. Norwegian hydro production last week peaked at 19.7GW on 13 March and averaged 17.9GW between 10 and 16 March, exceeding the monthly average of 15.9GW in March so far. Higher Norwegian hydro output was directly correlated with lower Swedish wind generation on those days, with Swedish average daily wind generation falling to 1.1GW and 1.5GW on 12 March and 13 March, respectively, while Norwegian hydro output topped 19GW on both days. By 15 and 16 March, Norwegian hydro production fell back to 16.6GW and 14.5GW, as Swedish wind generation rose to 7.6GW and 8.2GW. Unseasonably high reserves have consistently weighed on summer delivery power contracts and supported a substantial €59.20/MWh discount for Nordic June to the German equivalent on 18 March and an average discount of €59.13/MWh between 3 and 18 March. The Nordic third quarter last closed at a €66.10/MWh discount to the German equivalent and has averaged €67.23/MWh below Germany's front quarter over the previous 30 days. Reserves ended last month at 57.8pc of total capacity, some 3.4 percentage points above the 10-year maximum and in Norway, reserves were just 0.5 percentage points below the long-term national maximum, with stocks since switching to a 2.8 percentage point surplus to the maximum in week 10 and a 2.4 percentage point surplus in week 11. This was despite precipitation between October and February being up on the year, it remained below the region's seasonal norm by nearly 20.6mm, with rainfall in Bergen over the same period below the average in four of the past five years. Precipitation over the five months last exceeded the seasonal norm in 2022, totalling 1,804.8mm and registering a 422.9mm surplus to the average. But at February's close, hydro reserves in 2022 were 17.2 percentage points below the equivalent week in 2025, underscoring increased Swedish wind output's impact over the 2024-25 season. By Daniel Craig Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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UK wealth fund to prioritise ‘clean energy’ investment


19/03/25
News
19/03/25

UK wealth fund to prioritise ‘clean energy’ investment

London, 19 March (Argus) — The UK government has set "clean energy" as a priority investment sector for its new national wealth fund, and set out a plan for the fund to interact with newly-formed Great British Energy to drive decarbonisation. The two organisations will interact to provide a "strong end-to-end clean energy development and finance offer" and help the country hit its net zero targets, the government said. Great British Energy — staffed by specialists in the sector — will provide "development expertise", while the wealth fund will deliver finance, the government said. Great British Energy "will develop, invest in, build and operate clean energy projects across the UK", including owning stakes in the projects it develops itself, the government said. The organisation will develop "clean energy assets from inception", as well as co-develop and invest in more advanced projects. The national wealth fund "will unlock over £70bn ($90.7bn) in private investment to help deliver economic growth, make Britain a clean energy superpower, and strengthen the defence sector", the government said. The fund will prioritise investment in "clean energy, advanced manufacturing, digital technologies, and transport", and flagged likely spending on carbon capture and green hydrogen projects, as well as gigafactories and "green steel". The government has made commitments to "clean power" deployment and hitting the UK's legally-binding net zero by 2050 target central to its approach, sticking to pledges made ahead of last July's election . The government is targeting 95pc "clean power" by 2030 and consulted on a "clean energy future" for the North Sea earlier this month . By Georgia Gratton Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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