Raízen e BYD anunciam hubs de recarga de elétricos

Market: Battery materials, Biofuels, Electricity, Metals
02/02/24

A Raízen Power – braço de energia elétrica da sucroalcooleira Raízen – e a montadora chinesa BYD fecharam parceria para construir polos de recarga de veículos elétricos pelo Brasil.

A iniciativa criará centros para recarga de veículos elétricos com a solução Shell Recharge em oito capitais, utilizando energia de fonte renovável fornecida pela Raízen Power.

Cerca de 600 novos pontos de carregamento serão instalados, adicionando 18 megawatts (MW) de potência instalada para recarga no país, disse a Raízen – uma joint venture entre a Shell e o conglomerado Cosan.

O anúncio segue o início da construção do primeiro complexo industrial da BYD no Brasil, que produzirá 150.000 carros/ano na Bahia, com operações programadas para começar em dezembro.

"Vemos o continente como um mercado potencial para a BYD e a transição energética", contou Alexandre Baldy, conselheiro especial da empresa e ex-ministro das Cidades do governo Temer, à Argus.

A Associação Nacional dos Fabricantes de Veículos Automotores (Anfavea) projeta que as vendas de veículos elétricos movidos a bateria aumentem para 24.100 unidades em 2024, ante 15.200 no ano passado. A entidade prevê a alta mesmo considerando a volta da tarifa de importação em janeiro.

Por Laura Guedes

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13/06/25

EPA proposes record US biofuel mandates: Update

Updates with new pricing, reactions throughout. New York, 13 June (Argus) — President Donald Trump's administration today proposed requiring record biofuel blending into the US fuel supply over the next two years, including unexpectedly strong quotas for biomass-based diesel. The US Environmental Protection Agency (EPA) proposal, which still must be finalized, projects oil refiners will need to blend 5.61bn USG of biomass-based diesel to comply with requirements in 2026 and 5.86bn USG in 2027. Those estimates — while uncertain — would be a 67pc increase in 2026 and a 75pc increase in 2027 from this year's 3.35bn USG requirement, above what most industry groups had sought. The proposal alone is likely to boost biofuel production, which has been down to start the year as biorefineries have struggled to grapple with uncertainty about future blend mandates, the halting rollout of a new clean fuel tax credit, and higher import tariffs. The National Oilseed Processors Association said hiking the biomass-based diesel mandate to the proposed levels would bring "idled capacity back online" and spur "additional investments" in the biofuel supply chain. The EPA proposal also would halve Renewable Identification Number (RIN) credits generated from foreign biofuels and biofuels produced from foreign feedstocks, a major change that could increase US crop demand and hurt renewable diesel plants that source many of their inputs from abroad. US farm groups have lamented refiners' rising use of Chinese used cooking oil and Brazilian tallow to make renewable diesel, and EPA's proposal if finalized would sharply reduce the incentive to do so. Biofuel imports from producers with major refineries abroad, notably including Neste, would also be far less attractive. The proposal asks for comment, however, on a less restrictive policy that would only treat fuels and feedstocks from "a subset of countries" differently. And EPA still expects a substantial role for imported product regardless, estimating in a regulatory impact analysis that domestic fuels from domestic feedstocks will make up about 62pc of biomass-based diesel supply next year. The Renewable Fuel Standard program requires US oil refiners and importers to blend biofuels into the conventional fuel supply or buy credits from those who do. One USG of corn ethanol generates one RIN, but more energy-dense fuels like renewable diesel can earn more. In total, the rule would require 24.02bn RINs to be retired next year and 24.46bn RINs in 2027. That includes a specific 7.12bn RIN mandate for biomass-based diesel in 2026 and 7.5bn in 2027, and an implied mandate for corn ethanol flat from prior years at 15bn RINs. EPA currently sets biomass-based diesel mandates in physical gallons but is proposing a change to align with how targets for other program categories work. US soybean oil futures surged following the release of the EPA proposal, closing at their highest price in more than four weeks, and RIN credits rallied similarly on bullish expectations for higher biofuel demand and domestic feedstock prices. D4 biomass-diesel credits traded as high as 117.75¢/RIN, up from a 102.5¢/RIN settle on Thursday, while D6 conventional credits traded as high as 110¢/RIN. Bids for both retreated later in the session while prices still closed the day higher. Proposed targets are less aspirational for the cellulosic biofuel category, where biogas generates most credits. EPA proposes lowering the 2025 mandate to 1.19bn RINs, down from from 1.38bn RINs previously required, with 2026 and 2027 targets proposed at 1.30bn RINs and 1.36bn RINs, respectively. In a separate final rule today, EPA cut the 2024 cellulosic mandate to 1.01bn RINs from 1.09bn previously required, a smaller cut than initially proposed, and made available special "waiver" credits refiners can purchase at a fixed price to comply. Small refinery exemptions The proposal includes little clarity on EPA's future policy around program exemptions, which small refiners can request if they claim blend mandates will cause them disproportionate economic hardship. EPA predicted Friday that exemptions for the 2026 and 2027 compliance years could total anywhere from zero to 18bn USG of gasoline and diesel and provided no clues as to how it will weigh whether individual refiners, if any, deserve program waivers. The rule does suggest EPA plans to continue a policy from past administrations of estimating future exempted volumes when calculating the percentage of biofuels individual refiners must blend in the future, which would effectively require those with obligations to shoulder more of the burden to meet high-level 2026 and 2027 targets. Notably though, the proposal says little about how EPA is weighing a backlog of more than a hundred requests for exemptions stretching from 2016 to 2025. An industry official briefed on Friday ahead of the rule's release said Trump administration officials were "coy" about their plans for the backlog. Many of these refiners had already submitted RINs to comply with old mandates and could push for some type of compensation if granted retroactive waivers, making this part of the program especially hard to implement. And EPA would invite even more legal scrutiny if it agreed to biofuel groups' lobbying to "reallocate" newly exempted volumes from many years prior into future standards. EPA said it plans to "communicate our policy regarding [exemption] petitions going forward before finalization of this rule". Industry groups expect the agency will try to conclude the rule-making before November. The proposed mandates for 2026-2027 will have to go through the typical public comment process and could be changed as regulators weigh new data on biofuel production and food and fuel prices. Once the program updates are finalized, lawsuits are inevitable. A federal court is still weighing the legality of past mandates, and the Supreme Court is set to rule this month on the proper court venue for litigating small refinery exemption disputes. Environmentalists are likely to probe the agency's ultimate assessment of costs and benefits, including the climate costs of encouraging crop-based fuels. Oil companies could also have a range of complaints, from the record-high mandates to the creative limits on foreign feedstocks. American Fuel and Petrochemical Manufacturers senior vice president Geoff Moody noted that EPA was months behind a statutory deadline for setting 2026 mandates and said it would "strongly oppose any reallocation of small refinery exemptions" if finalized. By Cole Martin and Matthew Cope Proposed 2026-2027 renewable volume obligations bn RINs Fuel type 2026 2027 Cellulosic biofuel 1.30 1.36 Biomass-based diesel 7.12 7.50 Advanced biofuel 9.02 9.46 Total renewable fuel 24.02 24.46 Implied ethanol mandate 15 15 — EPA Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Law's sunset not an end for Argentina's renewables

13/06/25

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13/06/25

Law's sunset not an end for Argentina's renewables

Buenos Aires, 13 June (Argus) — A law meant to increase renewable energy in Argentina will expire at the end of 2025 without meeting its target and with little hope of renewal, but other incentives may still bolster the sector. Law 27191, passed in 2015 to extend earlier legislation, called for renewable sources to reach at least 20pc of Argentina's energy mix by the end of its 2025 expiry. The legislation covers biogas, biomass, solar, wind and hydroelectric plants under 50MW of capacity. Renewables have expanded more than other technologies, increasing to 6,672MW of installed capacity at the end of last year from 381MW in 2003, but still far from the goal. Renewable sources accounted for 15pc of installed capacity at the end of 2024 and covered 16pc of demand, according to the state-owned energy wholesale company, Cammesa. New capacity is being added and renewables should come close to meeting the demand target — renewables covered 21pc of demand in April, according to Cammesa, and 572MW in new solar and wind capacity came online in June alone. But it is unclear what comes next as the government deregulates the economy and pulls back from market intervention. Marcelo Alvarez, head of the solar power committee for Cader, Argentina's renewable energy association, said that there is no indication six months before the law's expiration that it will be extended. "I do not think they are going to extend Law 27191," he said. "The government is not interested in anything that conditions or interferes with the free-market dynamic and [Law] 27191, with its model of quotas with fiscal incentives, goes against its ideological thinking." But the government's change in policy approach could help address some of the main infrastructure and economic problems that hampered the installation of more renewable sources. Argentina has some of the world's best solar and wind potential, according to Alvarez, but it does not have the transmission lines to get power from new plants into the grid. "The system is basically saturated and we are really going to hit a wall if we do not start to build new lines now," said Alvarez. President Javier Milei's government announced in late May a plan for new transmission lines, but the private sector would need to do the work. The plan includes 15 500kV lines that would cover 5,610km and increase the existing grid's scope by 38pc at a cost of $6.6bn. The government is also moving forward with a tender started by the previous administration for a battery energy storage system (BESS) for 500MW, one of the largest in Latin America. The winning bids should be announced in August, according to the most recent timeline. The critical point for any project is financing, which Alvarez said remains difficult and expensive in Argentina despite recent changes. He said that interest rates for a 100MW project in Argentina are around 8pc, while in neighboring Chile they can be as low as 3pc. The Milei government has started to tackle major issues, bringing inflation down to 47.4pc annualized through April from nearly 300pc in 2024, eliminating regulations on financing and exports and reducing currency controls. It also has in place an investment and legal stability mechanism, known as Rigi, to attract large-scale investment for projects over $200mn. It has awarded one power project so far, the 305MW El Quemado solar park planned by state-owned YPF. "The cost and length of financing are major obstacles," Alvarez said. "It is going to take time to lower the cost of capital." By Lucien Chauvin Argentina's renewable power capacity MW Technology End 2024 Apr 25 Wind 4,319 4,342 Solar 1,673 1,909 Small hydro 524 524 Biogas/biomass 155 192 — Cammesa Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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EPA proposes record US biofuel mandates, foreign limits

13/06/25

News

13/06/25

EPA proposes record US biofuel mandates, foreign limits

New York, 13 June (Argus) — President Donald Trump's administration today proposed requiring record biofuel blending into the US fuel supply over the next two years, including unexpectedly strong quotas for biomass-based diesel. The US Environmental Protection Agency (EPA) proposal, which still must be finalized, projects that oil refiners will need to blend 5.61bn USG of biomass-based diesel to comply with requirements in 2026 and 5.86bn USG in 2027. That's a 67pc increase in 2026 and a 75pc increase in 2027 from this year's 3.35bn USG requirement, above what most industry groups had sought. The proposal alone is likely to boost biofuel production, which has been down to start the year as biorefineries have struggled to grapple with uncertainty about future blend mandates, the halting rollout of a new clean fuel tax credit, and higher import tariffs. The EPA proposal also would halve Renewable Identification Number (RIN) credits generated for foreign biofuels and biofuels produced from foreign feedstocks, a major change that could increase US crop demand and hurt renewable diesel plants that source many of their inputs from abroad. US farm groups have lamented refiners' rising use of Chinese used cooking oil and Brazilian tallow to make renewable diesel, and EPA's proposal if finalized would sharply reduce the incentive to do so. The Renewable Fuel Standard program requires US oil refiners and importers to blend biofuels into the conventional fuel supply or buy credits from those who do. One USG of corn ethanol generates one RIN, but more energy-dense fuels like renewable diesel can earn more. In total, the rule would require 24.02bn RINs to be retired next year and 24.46bn RINs in 2027. That includes a specific 7.12bn RIN mandate for biomass-based diesel in 2026 and 7.5bn in 2027, and an implied mandate for corn ethanol of 15bn RINs, similar to prior years. EPA currently sets biomass-based diesel mandates in physical gallons but is proposing a change to align with how targets for other program categories work. US soybean oil futures surged following the release of the EPA proposal, and RIN credits rallied similarly. Current year D6 credits, typically generated from conventional ethanol production, traded at 92¢/RIN near the opening of the session before peaking at 110¢/RIN and then retreating slightly. Current year biomass-based diesel D4 RINs followed a similar trajectory, trading up to 116¢/RIN and widening the gap with conventional D6 RINs. Proposed targets are less aspirational for the cellulosic biofuel category, where biogas generates most credits. EPA proposes lowering the 2025 mandate to 1.19bn RINs, down from from 1.38bn RINs previously required, with 2026 and 2027 targets proposed at 1.30bn RINs and 1.36bn RINs, respectively. In a separate final rule today, EPA cut the 2024 cellulosic mandate to 1.01bn RINs from 1.09bn previously required, a smaller cut than initially proposed, and made available special "waiver" credits refiners can purchase at a fixed price to comply. Small refinery exemptions The proposal includes little clarity on EPA's future policy around program exemptions, which small refiners can request if they claim blend mandates will cause them disproportionate economic hardship. EPA predicted Friday that exemptions for the 2026 and 2027 compliance years could total anywhere from zero to 18bn USG of gasoline and diesel. EPA plans to continue a policy from past administrations of estimating future exempted volumes when calculating the percentage of biofuels individual refiners must blend, effectively requiring those with obligations to shoulder more of the burden to meet high-level volume targets. EPA in the proposal said it plans to "communicate our policy regarding [exemption] petitions going forward before finalization of this rule". Industry groups expect the agency will try to conclude the rule-making before November. Notably though, the proposal says little about how EPA is weighing a backlog of more than a hundred requests for exemptions stretching back to 2016. Many of these refiners had already submitted RINs to comply and could push for some type of compensation if granted retroactive waivers, making this part of the program especially hard to implement. An industry official briefed on Thursday ahead of the rule's release said Trump administration officials were "coy" about their plans for the backlog. The proposed mandates for 2026-2027 will have to go through the typical public comment process and could be changed as regulators weigh new data on biofuel production and food and fuel prices. Once the program updates are finalized, lawsuits are inevitable. A federal court is still weighing the legality of past mandates, and the Supreme Court is set to rule this month on the proper court venue for litigating small refinery exemption disputes. By Cole Martin and Matthew Cope Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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CBAM to push renewable power export price above lignite

13/06/25

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13/06/25

CBAM to push renewable power export price above lignite

London, 13 June (Argus) — Exports from renewable power production from Energy Community constituent states to the EU could cost more per MWh than exports from lignite-fired generation under the current implementation of the EU's carbon border adjustment mechanism (CBAM), Energy Community CBAM lead Peter Pozsgai said at the Energy Trading Central and South Eastern Europe (ETCSEE) conference in Vienna on 12 June. CBAM will be applied to all cross-border electricity flows from Energy Community states, including power generated from renewables. Producers will be able to deduct any payments made into a regional carbon tax or emissions trading system (ETS) equivalent — a key pillar of market coupling as laid out in 2022's energy integration package. But renewable energy producers will not pay into a regional carbon tax or ETS equivalent, and thus will not be able to deduct this carbon tax from the CBAM applied to all electricity exports. In effect, exports from renewable sources will be priced higher than those from lignite-fired plants in the Western Balkans six — Albania, Bosnia and Herzegovina, Kosovo, North Macedonia, Montenegro and Serbia. Pozsgai "hopes this can be amended" and emphasised that the Energy Community and the European Commission will hold a stakeholder meeting on 1 July with the aim of providing more clarity on CBAM's implementation. Electricity is treated separately from other physical commodities under the CBAM legislation. Carbon quantity will be based on average country-wide emissions rather than on individual plant efficiency. Each country's CO2 emissions factor will be calculated as the weighted-average emissions from all fossil fuel-fired generation in the country and is higher than the indirect emissions factor applied to other goods that are subject to CBAM when they enter the EU. This weighted-emissions factor will be applied to all cross-border power exports, regardless of generation source. CBAM loomed over discussions at ETCSEE, with the regulation being discussed on every panel over the two-day event. Market participants already have observed lower forward liquidity as uncertainty mounts on how CBAM will be implemented and expressed concern about taking financial positions while CBAM implementation evolves. But trading firms and regulators alike expressed a desire for market coupling, while acknowledging that CBAM's implementation instead may hinder regional market integration. "Regional integration is hugely important for security of supply and efficiency and should move forward regardless of CBAM, and if they meet requirements, there should be discussions of [CBAM] being lifted," according to the European Commission's deputy head of unit of the Directorate-General for Energy, Andras Hujber. "Price sensitivity will increase with the implementation of CBAM," Hungarian state-owned energy firm MVM chief commercial officer Laszlo Fritsch said. Provisions in the 2022 integration package provided a pathway to a four-year exemption for Energy Community states, provided they complete market coupling measures before CBAM's scheduled start on 1 January 2026. But no Energy Community countries have met these requirements yet. Serbia will be the first country to couple with EU neighbours Hungary and Romania in the fourth quarter of 2026, but it is unclear whether a CBAM exemption will be granted from that point forward or applied retroactively. European power transmission system operator association Entso-E earlier this week asked the EU to postpone the definitive period of CBAM to provide electricity markets with more time to adjust. By Annemarie Pettinato Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Australia allows emissions reporting for biomethane, H2

13/06/25

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13/06/25

Australia allows emissions reporting for biomethane, H2

Sydney, 13 June (Argus) — The Australian government will enable companies to report scope 1 emissions from the consumption of biomethane and hydrogen, which will need to be backed by eligible renewable gas certificates, it announced today. Companies will be able to prove that the gas they receive from the natural gas network and consume in a reporting year contains an amount of renewable gas, as represented by renewable gas certificates retired or completed by them or on their behalf, adjusted for losses, the Department of Climate Change, Energy, the Environment and Water (DCCEEW) said on 13 June. The new product guarantee of origin (PGO) certificates registered under the guarantee of origin (GO) scheme, as well as the renewable gas guarantee of origin (RGGO) certificates issued under the GreenPower Renewable Gas Certification (RGC), will both be allowed. Any gas sourced from the natural gas network that is not covered by the new certificate-backed loss-adjusted amount must be reported as natural gas, the DCCEEW said. The changes are part of updates to the National Greenhouse and Energy Reporting (NGER) scheme, which is used to measure and report greenhouse gas (GHG) emissions and energy production and consumption. These are the latest changes following the implementation of the recommendations made at the end of 2023 by Australia's Climate Change Authority (CCA), which reviews the NGER scheme every five years. The market-based reporting allowing companies to report the scope 1 emissions benefits from their renewable gas purchases will start from 1 July 2025, and be applicable from the July 2025-June 2026 financial year onwards. They will affect NGER scheme reports to be submitted by corporations by 31 October 2026. The updates also include amendments to support the reclassification of hydrogen as a fuel type. Hydrogen was previously classified in the NGER scheme as an energy commodity. The DCCEEW will monitor the uptake of biomethane as a feedstock for ammonia and hydrogen production and may revisit some technical rules in future annual NGER scheme updates, it said. Potential impact on oil and gas facilities Other changes announced on 13 June include updates to the emission factors used in two methods for gas flared in oil and natural gas operations. Some submissions to a public consultation raised concerns about the potential overestimation of methane emissions resulting from the assumption that flare gas is 100pc methane, and implications of the proposed emission factors on facilities covered by the safeguard mechanism, the DCCEEW said. The Clean Energy Regulator has the discretion to vary the facility's baseline to accommodate the regulatory change if the revised factors have a material impact on emissions reported by a facility covered by the safeguard mechanism, it said. Facilities under the oil and gas extraction sector received a combined 3.07mn safeguard mechanism credits (SMCs) in the July 2023-June 2024 financial year as their covered scope 1 emissions were below their baselines. By Juan Weik Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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