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Korea updates laws to promote biofuels, energy security

  • Market: Biofuels, Hydrogen
  • 10/01/24

South Korea passed amendments to its laws on 9 January which will make it easier to produce biofuels via co-processing, refiners said.

Refiners will no longer need to get government approval for co-processing, as biofuels feedstocks that were previously not officially registered as feedstock to oil refineries have now been so registered, they said.

Refiners now have the green light to supply co-processed biofuels domestically and internationally, and can use those fuels to meet South Korea's national biofuels mandates.

The Korean National Assembly passed an amendment to the Petroleum and Alternative Fuels Business Act on 9 January. This was to encourage more investment from the domestic oil industry in eco-friendly fuels — namely biofuels and renewable synthetic fuel — as well as achieve carbon neutrality.

The amendment will be promulgated after being transferred to the government and approved by the State Council, and implemented six months later.

It will allow the input of "eco-friendly refining raw materials" designated by the ministry of trade, industry and energy (Motie) into the oil refining process and help establish a stable supply chain of environmentally-friendly fuels.

New regulations have also been established to allow the use of waste plastic pyrolysis oil, waste lubricants and biomass in the refining process. These will also encourage private-sector investment in biofuels.

There was a meeting held with authorities and companies in the biofuels space to gather industry feedback on the amended laws on the afternoon of 10 January, sources from two South Korean companies said. The agenda included discussions on bio marine fuels and supply difficulties, challenges in using B100 biodiesel, and challenges related to greenhouse gas emissions from different feedstocks under the International Maritime Organisation's (IMO's) Carbon Intensity Indicator (CII) ratings.

Energy security, CCUS legislation

South Korea has also passed legislative acts to enhance energy and mineral supply security.

The country passed the Special National Resource Security Act, given "the trend of resource weaponisation in major countries and geopolitical crises such as the Russia-Ukraine war and the Israel-Hamas crisis", according to Motie on 9 January, especially since South Korea relies on imports for over 90pc of its energy.

The act designates oil, natural gas, coal, hydrogen, key minerals, as well as materials and components used in new and renewable energy facilities as "core resources". It also includes the stockpiling of resources, analysing supply chain vulnerabilities, operating early warning systems, as well as supporting the expansion of domestic and overseas production.

South Korea also passed an act on carbon capture, utilisation and storage (CCUS) to "prepare the legal foundation needed to respond to the climate crisis and foster the CCUS industry", Motie said. The act lays out the process for securing and operating CO2 storage, as well as special provisions for CO2 supply, among others. It also includes various regulations aimed at supporting corporate research and development.

The CCUS Act will be promulgated after receiving approval from the State Council, and implemented a year after its promulgation.

"The enactment of the CCUS Act has contributed to carbon neutrality and laid the basis for administrative and financial support for CCUS-related technology development and industrial development," energy policy officer Choi Yeon-woo said.


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17/10/24

Jury rules against P66 in trade secret case

Jury rules against P66 in trade secret case

Calgary, 17 October (Argus) — A California jury says US independent refiner Phillips 66 must pay $604.9mn in damages for allegedly stealing trade secrets related to the state's biofuels market. The jury issued its verdict on 16 October, siding with west coast fuel retailer Propel Fuels more than two years after it filed suit in the Superior Court of California. Propel sought $1bn in damages , alleging that Phillips 66's renewables business in California was developed from trade secrets the refiner gained while conducting due diligence on for a possible acquisition of the fuel retailer in 2017 and 2018. Propel said it was "... actively building a new integrated renewable fuels business for Phillips 66 when Phillips 66 abruptly and without explanation terminated the deal on August 24, 2018." Shortly after terminating the deal, the refiner told California regulators it would begin selling E85 fuel in the state and launched retail sales of renewable diesel (RD) weeks later, Propel says. "Phillips 66 rapidly expanded its California renewables business using Propel's data and market insights," according to Propel. Phillips 66 denied any wrongdoing and said it is evaluating its legal options following the verdict. A final judgment in the case has not been entered and post-trial motions are pending before the court, Phillips 66 said. By Brett Holmes Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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Indonesia to restrict palm residue exports from 25 Oct


16/10/24
News
16/10/24

Indonesia to restrict palm residue exports from 25 Oct

Singapore, 16 October (Argus) — Indonesia's ministry of trade will introduce an export permit requirement on palm oil residues, which are often used as biofuels feedstocks, effective from 25 October. The residues consist of palm oil mill effluent (Pome) oil, high acid palm oil residue (Hapor), and empty fruit bunch (EFB) oil. They fall under HS codes 2306.60.90 and 2306.90.90, and join existing restrictions on palm derivative products including refined, bleached, and deodorised (RBD) palm oil, RDB palm olein and used cooking oil (UCO). Exporting entities now have to fulfil their cooking oil domestic market obligation (DMO) before they can receive an export permit for Pome oil, Hapor and EFB oil. To fulfill the DMO, companies need to sell palm oil into the domestic market at a ratio of 4:1 for loose oil or 9:1 to packaged oil as part of the Minyak Goreng Rakyat (MGR) programme. The inclusion of residue products such as Pome oil means even exporting entities dealing with only Pome oil will now have to participate in the domestic vegetable oil market to fulfil the DMO. This may squeeze some participants out of the market should they be unable to compete with bigger participants. Alternatively, exporting entities that do not trade vegetable oil may choose to purchase export permits from entities which have met the DMO on cooking oil, which would increase Pome export cost. Some participants estimate the restriction will drive an increase of around $10-20/t in Pome oil export costs, based on current palm oil prices. Some participants also believe the new restriction is likely to tighten supply and act as a Pome oil fraud prevention measure. The announcement comes just as delegations from Ireland, Belgium, Germany and the Netherlands filed an information note for the European Commission's transport, telecommunications and energy council meeting on 15 October. They asked the commission to look into concerns about Pome oil and other palm oil derivatives used as waste-based biofuel feedstocks in Europe, implying that the EU consumed more Pome oil-based biofuels than could theoretically have been produced. But the Indonesian Pome oil market had been expecting a restriction on Pome exports tied to the MGR programme as far back as in August . The restriction is considered a second blow to the Indonesian Pome oil export market this year as the ministry previously raised export levies on palm waste and residue biofuel feedstocks , moving the export levy on Pome oil from $5/t to $63/t in September, which weighed heavily on Pome oil market liquidity. Participants have also observed that Indonesian Pome oil should be valued higher than Malaysian cargoes as the higher export levy, and now export permit requirement, has driven up the cost for supplying Pome oil out of Indonesia. The fob Indonesia/ Malaysia Pome oil assessment stood at a midpoint of $810/t on 15 October, the highest in five months. By Deborah Sun Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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Tax credit delay risks growth of low-CO2 fuels


15/10/24
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15/10/24

Tax credit delay risks growth of low-CO2 fuels

New York, 15 October (Argus) — A new US tax credit for low-carbon fuels will likely begin next year without final guidance on how to qualify, leaving refiners, feedstock suppliers, and fuel buyers in a holding pattern. The US Treasury Department this month pledged to finalize guidance around some Inflation Reduction Act tax credits before President Joe Biden leaves office but conspicuously omitted the climate law's "45Z" incentive for clean fuels from its list of priorities. Kicking off in January and lasting through 2027, the credit requires road and aviation fuels to meet an initial carbon intensity threshold and then ups the subsidy as the fuel's emissions fall. The transition to 45Z was always expected to reshape biofuel markets, shifting benefits from blenders to producers and encouraging the use of lower-carbon waste feedstocks, like used cooking oil. And the biofuels industry is used to uncertainty, including lapsed tax credits and retroactive blend mandates. But some in the market say this time is unique, in part because of how different the 45Z credit will be from prior federal incentives. While the credit currently in effect offers $1/USG across the board for biomass-based diesel, for example, it is unclear how much of a credit a gallon of fuel would earn next year since factors like greenhouse gas emissions for various farm practices, feedstocks, and production pathways are now part of the administration's calculations. This delay in issuing guidance has ground to a halt talks around first quarter contracts, which are often hashed out months in advance. Renewable Biofuels chief executive Mike Reed told Argus that his company's Port Neches, Texas, facility — the largest biodiesel plant in the US with a capacity of 180mn USG/yr — has not signed any fuel offtake contracts past the end of the year or any feedstock contracts past November and will idle early next year absent supportive policy signals. Biodiesel traders elsewhere have reported similar challenges. Across the supply chain, the lack of clarity has made it hard to invest. While Biden officials have stressed that domestic agriculture has a role to play in addressing climate change, farmers and oilseed processors have little sense of what "climate-smart" farm practices Treasury will reward. Feedstock deals could slow as early as December, market participants say, because of the risk of shipments arriving late. Slowing alt fuel growth Recent growth in US alternative fuel production could lose momentum because of the delayed guidance. The Energy Information Administration last forecast that the US would produce 230,000 b/d of renewable diesel in 2025, up from 2024 but still 22pc below the agency's initial outlook in January. The agency also sees US biodiesel production falling next year to 103,000 b/d, its lowest level since 2016. The lack of guidance is "going to begin raising the price of fuel simply because it is resulting in fewer gallons of biofuel available," said David Fialkov, executive vice president of government affairs for the National Association of Truck Stop Operators. And if policy uncertainty is already hurting established fuels like biodiesel and renewable diesel, impacts on more speculative but lower-carbon pathways — such as synthetic SAF produced from clean hydrogen — are potentially substantial. An Argus database of SAF refineries sees 810mn USG/yr of announced US SAF production by 2030 from more advanced pathways like gas-to-liquids and power-to-liquids, though the viability of those plants will hinge on policy. The delay in getting guidance is "challenging because it's postponing investment decisions, and that ties up money and ultimately results in people perhaps looking elsewhere," said Jonathan Lewis, director of transportation decarbonization at the climate think-tank Clean Air Task Force. Tough process, ample delays Regulators have a difficult balancing act, needing to write rules that are simultaneously detailed, legally durable, and broadly acceptable to the diverse interests that back clean fuel incentives — an unsteady coalition of refiners, agribusinesses, fuel buyers like airlines, and some environmental groups. But Biden officials also have reason to act quickly, given the threat next year of Republicans repealing the Inflation Reduction Act or presidential nominee Donald Trump using the power of federal agencies to limit the law's reach. US agriculture secretary Tom Vilsack expressed confidence last month that his agency will release a regulation quantifying the climate benefits of certain agricultural practices before Biden leaves office , which would then inform Treasury's efforts. Treasury officials also said this month they are still "actively" working on issuing guidance around 45Z. If Treasury manages to issue guidance, even retroactively, that meets the many different goals, there could be more support for Congress to extend the credit. The fact that 45Z expires after 2027 is otherwise seen as a barrier to meeting US climate goals and scaling up clean fuel production . But rushing forward with half-formed policy guidance can itself create more problems later. "Moving quickly toward a policy that sends the wrong signals is going to ultimately be more damaging for the viability of this industry than getting something out the door that needs to be fixed," said the Clean Air Task Force's Lewis. By Cole Martin Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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Tidewater terminal adds biodiesel blending


15/10/24
News
15/10/24

Tidewater terminal adds biodiesel blending

New York, 15 October (Argus) — US commodity transportation company Tidewater will soon be able to blend over 2mn USG of biodiesel per month at one of its terminals in Washington state, enabling broader use of renewable fuels in the region. The company said the new biofuel facility at its Snake River Terminal in Pasco, Washington, will be operational "by the end of this week." The addition to the terminal will also allow for loading neat biodiesel for distribution to other blending sites in eastern Washington and in nearby Oregon. The terminal can store 9mn USG of petroleum and renewable diesel that can now be blended with up to 20pc biodiesel depending on customer requests, Tidewater said. The US Department of Agriculture helped fund the project through a $3.1mn grant last year as part of the agency's Higher Blends Infrastructure Incentive Program. The office of senator Maria Cantwell (D-Washington), which supported the funding request, said at the time that the plan was to make more renewable fuels available to farmers, local gas stations, and potentially to BNSF Railway. Crucially, Washington is one of just three states in the US with a low-carbon fuel standard program, which requires yearly reductions in transportation fuel carbon intensity and helps subsidize biofuel production. Higher-carbon fuels exceeding the annual limit incur deficits that suppliers must offset with credits generated from the distribution of approved lower-carbon alternatives, including fuels like biodiesel and renewable diesel. Oregon has a similar program. By Cole Martin Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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Chinese steel investment needs to avoid lock in: CBI


15/10/24
News
15/10/24

Chinese steel investment needs to avoid lock in: CBI

Singapore, 15 October (Argus) — Chinese investment in steel assets needs to be aligned with a Paris-compatible scenario to avoid locking in emissions and stranded assets, according to a report by non-profit Climate Bonds Initiative (CBI). Almost 80pc or 730.8mn t/yr of China's existing coal-based blast furnace capacity will need to be retired or require reinvestment by 2030, CBI said in its report released last week. Steel asset lifetimes often exceed 40 years, so "investment decisions made today can lock in billions of tons of emissions and potentially billions of dollars in stranded assets", CBI added. Steel production currently accounts for around 8pc of global CO2 emissions, and almost 50pc of global steel output is from China, CBI said. China's steel sector is estimated to require at least 1.6 trillion yuan ($226bn) in fixed asset investment for decarbonisation by 2050, according to a joint report by CBI and US-based Rocky Mountain Institute (RMI) earlier this year. Of the Yn1.6 trillion, 33pc should go to energy efficiency, 23pc for electric arc furnaces, 18pc for direct iron reduction (DRI), 14pc for carbon capture, utilisation and storage (CCUS), 7pc for blast furnace hydrogen injection, and 5pc for pellet manufacturing. Green bonds Steel companies can obtain financing through labelled green bonds from various categories at the project level, including energy efficiency, heat recycling, waste and resource recycle, green hydrogen, biomass, and CCUS. A total of Yn4.46 trillion of labelled green bonds had originated from China in domestic and overseas markets as of the end of 2023, according to CBI. But Chinese steel firms had only issued 23 green bonds totalling Yn3.5bn and six sustainability-linked bonds totalling Yn1.6bn by the end of last year, representing 0.1pc of the total Chinese labelled bond market. This Yn5.1bn falls very short of the estimated Yn1.6 trillion needed to decarbonise the Chinese steel sector. CBI asserts that the labelled bond and loan market can supply the required capital, but issuers operating in the steel sector must be encouraged to price deals with the recommended transparency and credibility. Recommendations Several Chinese provinces have already issued provincial-level transition finance guidance, including major steel-producing Hebei province this year. But China's national-level transition finance guidance remains under development. CBI thus recommends that the national transition taxonomy further align provincial guidelines and "enhance interoperability" between Chinese and international transition taxonomies, incentivise low-carbon production methods, customise financing for small-to-medium companies, and enhance entity-level transition plans. CBI also suggests that banks incentivise companies to enhance the quality of their information disclosure and integrate such incentives into their transition frameworks. The non-profit also urged steel companies to issue credible transition plans, which should include Paris-aligned emission-reduction targets and clear capital expenditure plans. Lastly, CBI notes that policies should support hydrogen infrastructure and supply chain development to accelerate green hydrogen deployment for high-emitting sectors. This is especially as current financing to decarbonise heavy industrial sectors have mainly been for mature technologies, such as raising energy efficiency. But green hydrogen can reduce over 90pc of steel production emissions, and steady development in hydrogen infrastructure and supply chain will cut costs and accelerate the steel transition. CBI also flagged public sector steel procurement as an avenue through which the country can boost demand for green steel, especially since Chinese public authorities buy about 350mn t/yr of steel, which causes around 689mn t/yr of CO2 emissions. Green public procurement (GPP) policies in China would also have a global impact, with steel public procurement demand in China three times that of India's total steel demand of 100mn t/yr. CDI suggests that the Chinese government accelerate adopting national-level standards to ensure consistent embodied emissions reporting, as GPP policies will only be effective when implemented with standardised methodologies. By Tng Yong Li Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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