

Carbon markets
Overview
Carbon markets are developing as a crucial economic lever in the challenge of reversing the accumulation of greenhouse gases in the Earth’s atmosphere, while CO2 remains a key factor in a range of industrial sectors.
National governments are embracing carbon markets, with a proliferation of carbon pricing policies worldwide. The private sector is channelling finance into projects that generate carbon emissions reductions and removals to mitigate their hard-to-abate emissions.
And the United Nations is making progress in building a global marketplace for carbon emissions reductions that will facilitate nations’ attempts to meet their obligations under the Paris Agreement.
Industrial sectors remain a key source of CO2 emissions and consumption, with innovation looking towards sustainable methods of production and utilisation.
Argus is setting the stage for an extended period of growth, evolution and interconnection of carbon market participants and initiatives.
Latest carbon markets news
Browse the latest market moving news on carbon markets.
Netherlands publishes RED III biofuels draft
Netherlands publishes RED III biofuels draft
London, 24 June (Argus) — The Dutch government's updated draft legislation to transpose the EU's revised Renewable Energy Directive (RED III) notably proposes abolishing double-counting renewable energy contributions from Annex IX feedstocks. The draft introduces a greenhouse gas (GHG) emission reduction mandate for land, inland shipping and maritime shipping, but excludes aviation — which was included in a previous draft . The RED III mandate will take effect in 2026. Obligated parties have to fulfil the mandate by surrendering a sufficient amount of so-called emission reduction units (EREs) in each sector. The mandate's flexible credit allowance allows EREs generated in the land sector to be used to partly meet emission reduction obligations in inland and maritime shipping ( see table ), but EREs from inland and maritime shipping cannot be used by land sector suppliers to fulfil their compliance requirements. Fuel suppliers with overall consumption of more than 500,000 l/yr will need to incorporate a 14.4pc share of renewable fuels in their annual deliveries in 2026. This increases linearly, to reach 27.1pc in 2030. The amount of crop-based biofuels in the land sector will be limited to 1.4pc of the overall energy content of total consumption until 2030, and will not be accepted towards targets in maritime and inland shipping and aviation. The amount of Annex IX Part B biofuels — such as used cooking oil (UCO) and animal fats categories 1 and 2 — that can be counted towards the mandate will be limited to 4.29pc in the land sector and 11.07pc in inland shipping. Obligated parties will be unable to claim EREs from Annex IX Part B fuels used in maritime shipping. The draft also introduces a minimum share of emission reductions that have to be achieved by Annex IX Part A and renewable fuels of non-biological origin (RFNBO), for all sectors. RED III mandates that 5.5pc of all fuels supplied must be advanced biofuels, including at least 1pc RFNBOs by 2030. The Netherlands' draft decouples these targets, to reduce investment uncertainty ( see table ). Refineries that use renewable hydrogen in their production process can claim refinery reduction units — or RAREs — which can be used by a supplier to meet an RFNBO sub-target in various sectors. Correction factor delay The ministry will delay its plans to apply a "correction factor" of 0.4 to its "refinery route" stimulus for hydrogen demand, in order to ensure the measure does not undermine direct use of hydrogen in transport. The correction factor means the value of emissions reductions credits generated through the use of renewable hydrogen for transport fuel production would be limited to a certain percentage of those generated through direct use of renewable hydrogen or derivatives in transport. The government leaves the option open to impose a correction factor from 2030. Although the EU Fuel Quality Directive increases the maximum share of bio-based components to 10pc in diesel, the Dutch government said fuel suppliers must continue to offer B7 — diesel with up to 7pc biodiesel — as a protection grade, because of the large number of cars incompatible with B10. Companies will be able to carry forward any excess EREs to the next compliance year. Companies with an annual obligation can carry forward up to 10pc of the total amount of EREs needed to fulfil their obligation in a year, with registering companies allowed to carry forward 4pc. Dutch renewable fuel tickets (HBEs) carried into 2026 will be converted into EREs on 1 April 2026, the government said. By Evelina Lungu and Anna Prokhorova Overview of future Dutch obligations pc CO2 2026 2027 2028 2029 2030 Land (Road) Sector-Specific Obligation 14.4 16.4 22.8 24.8 27.1 Flexible Credit Allowance 0.0 0.0 0.0 0.0 0.0 Total Obligation 14.4 16.4 22.8 24.8 27.1 Annex 9A Sub-Obligation 3.1 4.5 5.9 7.3 8.8 RFNBO Sub-Obligation 0.1 0.1 0.4 0.8 1.1 Conventional Biofuel Limit 1.2 1.2 1.2 1.2 1.2 Annex 9B Limit 4.3 4.3 4.3 4.3 4.3 Maritime Sector-Specific Obligation 3 3 4 5 6 Flexible Credit Allowance 1 2 2 2 3 Total Obligation 4 5 6 7 8 Annex 9A Sub-Obligation - - - - - RFNBO Sub-Obligation 0 0 0 0 0 Conventional Biofuel Limit 0 0 0 0 0 Annex 9B Limit 0 0 0 0 0 Inland Waterways Sector-Specific Obligation 3 4 6 8 12 Flexible Credit Allowance 1 1 2 2 3 Total Obligation 4 5 8 10 15 Annex 9A Sub-Obligation - - - - - RFNBO Sub-Obligation 0 0 0 0 0 Conventional Biofuel Limit 0 0 0 0 0 Annex 9B Limit 11 11 11 11 11 The Ministry of Infrastructure and Water Management *RFNBO: Renewable fuel of non-biological origin Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
GS Caltex explores new Pome treatment in Indonesia
GS Caltex explores new Pome treatment in Indonesia
Singapore, 24 June (Argus) — South Korean refiner and petrochemical producer GS Caltex has launched a six-month feasibility study into a new technology to reduce methane emissions from palm oil mill effluent (Pome) treatment in Indonesia, the world's largest producer and exporter of palm oil. The project will evaluate the potential for an evaporative concentration treatment facility, which GS Caltex estimates will cut methane emissions from Pome treatment by 120,000 t/yr of CO2 equivalent, while also recycling the Pome. South Korea's economy and finance ministry and Export-Import Bank will back the project. Pome is a liquid byproduct of palm oil milling. The oil fraction of this effluent is used as a feedstock in production of biofuels such as sustainable aviation fuel. Pome is typically stored in open-air anaerobic ponds at the palm oil mill, where the effluent is left to anaerobically digest for several weeks, releasing significant amounts of methane. Some palm oil producers cover the ponds to collect the methane, which can then be used for electricity generation. GS Caltex's proposed facility would treat the Pome immediately after generation to prevent decomposition and enable greater methane reduction. If implemented, this would be the first such facility in Indonesia. The company will make a decision on financing and logistics after the feasibility study. This project is part of a government initiative that provides financial support for companies' overseas greenhouse gas reduction projects. By Haridas Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
Erex to start Vietnam biomass co-firing tests in August
Erex to start Vietnam biomass co-firing tests in August
Tokyo, 24 June (Argus) — Japanese renewable energy developer Erex plans to start coal and biomass co-firing test runs at thermal power plants in Vietnam from August. Co-firing test runs will start at the 110MW Na Duong plant in August and at the 115MW Cao Ngan plant in September, Erex said on 20 June. Both plants are owned and operated by Vietnam National Coal and Mineral Industries (Vinacomin). The Japanese company announced in April that it was planning co-firing test runs at the two plants , but had not previously disclosed when the tests would start. The trial operations are expected to last for several months and burn locally produced wood chips, starting from 5pc co-firing and gradually increasing to 20pc. The two companies will renovate the plants in 2026-27 after the trial operations and start commercial co-firing operations around 2027-28, Erex said. Erex said it also plans to conduct co-firing test runs at Vinacomin's 670MW Cam Pha plant in 2027-28 and start commercial operations around 2029-30. The company aims to carry out co-firing at six Vinacomin plants with a combined capacity of 1,585MW, including Na Duong, Cao Ngan, and Cam Pha. The co-firing projects are part of Vietnam's net zero strategy. Erex is eyeing carbon credits from the plants once commercial co-firing begins. The company aims to sell some of the carbon credits in Japan and is currently negotiating with Vietnamese government on this. Erex is expanding its renewable energy business in Vietnam and southeast Asia. In addition to co-firing projects, the company aims to operate a total of 19 biomass-fired power plants in Vietnam. The first of these, the 20MW Hau Giang plant, started commercial operations in April. Erex also plans to build up to five biomass-fired power plants in Cambodia. The company projects that profits from Vietnam and Cambodia will account for more than half of its overall earnings by around 2030, from nearly negligible levels in 2024. By Takeshi Maeda Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
Ontario weighs domestic biomass-based diesel quota
Ontario weighs domestic biomass-based diesel quota
New York, 23 June (Argus) — Ontario is considering requiring that domestically produced renewable fuels make up 3pc of the province's diesel pool, an effort to help biodiesel producers struggling to adapt to policy changes in the US. Ontario late last week requested input on a proposal to supplement existing provincial biofuel blend requirements with a new mandate for Canadian production, similar to a domestic content rule that took force in British Columbia this year. Ontario already requires that renewables like biodiesel and renewable diesel make up 4pc of diesel consumption each year, but this proposal would require that three-fourths of that mandated volume come from biofuels produced in Canada. The Ontario Ministry of the Environment, Conservation and Parks says the proposal is in response to a new clean fuel tax credit that took effect in the US this year, which can only be claimed by US producers. A US Department of Agriculture report late last year said that there were six remaining operational biodiesel plants in Canada and that the industry has historically sent almost all its fuel into the US, which up until this year treated foreign biodiesel as eligible for a federal tax credit. At the same time, US biofuels have increasingly entered Canada to meet demand from low-carbon fuel standards federally and in British Columbia. In those programs, higher-carbon fuels that exceed annual carbon intensity limits incur deficits that suppliers must offset with credits generated from approved lower-carbon alternatives. The Canadian biofuel industry has pushed officials to respond. British Columbia as a result began requiring this year that renewables make up a minimum 8pc of diesel fuels supplied in the province, up from 4pc, and that this mandated volume must come from Canadian producers starting in April. British Columbia-based renewable diesel producer Tidewater Renewables has also unsuccessfully pushed Canada to impose duties on US product. The Ontario environment ministry said the domestic mandate, if finalized, would be a "temporary, time-limited measure" that would last as long as US subsidies "threaten Ontario's biodiesel industry." The new US tax credit that excludes foreign refiners is currently set to lapse after 2027, but Republican lawmakers have floated using a massive budget bill they want to pass in the coming weeks to extend the incentive through 2031. While full regulatory text is not available, as is typical for this early stage of the Ontario rulemaking process, it appears the proposal would otherwise keep intact the general structure of the province's biofuel mandate. The program offers more credit to lower-carbon fuels, which led to a slightly lower than 4pc biofuel blend rate for the diesel pool in 2023, according to a report from trade group Advanced Biofuels Canada. The domestic content proposal would also not affect a separate mandate that biofuels make up increasing amounts of the gasoline pool through 2030. By Cole Martin Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
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