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Japan backs coal-led decarbonisation in SE Asia
Japan backs coal-led decarbonisation in SE Asia
Tokyo, 4 September (Argus) — Japan is keen to support "realistic" decarbonization efforts in Southeast Asia while continuing to use coal, delegates heard at the 35th Clean Coal Day International Symposium held in Tokyo on 3 September. Japan will accelerate working together with Southeast Asian countries to support the continued use of coal while reducing carbon emissions, including through ammonia co-firing projects in Malaysia, Takahiro Tajiri, director-general for international affairs at the Agency for Natural Resources and Energy under Japan's ministry of economy, trade and industry Meti, said in a speech at the symposium. Japan has achieved a 20pc of ammonia co-firing with coal during trial operations at the 1GW No.4 coal-fired unit at the Hekinan power plant and aims to raise the co-firing rate to 50pc in the future. Japan can leverage this technology to support Malaysia and other countries in the region, according to Tajiri. Maintaining coal use while reducing carbon emissions through co-firing with renewable fuels such as ammonia and biomass is a "realistic" pathway for many countries, including Japan and those in Southeast Asia, Tajiri said. Coal remains affordable and provides a stable source of energy supply, he added. Japan should help Southeast Asian countries balance energy security and decarbonization through coal-related technologies, including ammonia co-firing, Paul Baruya, director of strategy and sustainability at Future Coal Global Alliance, said at the symposium. Coal has proven to be an alternative fuel to natural gas in many Asian countries when the de facto closure of the strait of Hormuz caused a sudden and unexpected disruption to LNG supply , Yoshikazu Kobayashi, chief economist and director for research strategy and energy security at the Institute of Energy Economics, Japan (IEEJ), said in his speech. By Takeshi Maeda Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
India eyes mandatory storage for new solar, wind plants
India eyes mandatory storage for new solar, wind plants
Mumbai, 4 September (Argus) — India's power sector regulator, the Central Electricity Authority (CEA), has proposed mandatory co-located energy storage for new ground-mounted solar and onshore wind projects, alongside grid-forming requirements for renewable power plants. Projects commissioned after 1 July 2027 would need co-located energy storage systems (ESS) with a minimum two-hour duration and capacity equivalent to at least 10pc of installed plant capacity, according to the draft CEA regulations released on 3 September. The storage-duration requirement would increase to four hours for ground-mounted solar and onshore wind projects commissioned after 1 July 2029 and up to 30 June 2031, while the capacity requirement would remain at 10pc of installed capacity. A 100MW solar or wind project would therefore need at least 10MW of storage, with a minimum energy capacity of 20MWh under the first phase and 40MWh under the four-hour requirement. The proposal comes as India's battery storage deployment accelerates. The country added 2,668.54MW of battery energy storage system (Bess) power capacity, equivalent to 7,785.6MWh of energy storage capacity, during 2026, according to government data. Around 47GW of Bess is also being considered for integration by 2031-32. India's solar and wind capacity has continued to expand rapidly. Solar capacity stood at 164.59GW and wind at 58.14GW as of 31 July, accounting for around 74pc of the country's 300.51GW of non-fossil installed capacity, data from the ministry of new and renewable energy (MNRE) show. Ground-mounted solar accounted for 122.57GW of the total solar capacity, while India added 14.33GW of solar and 2.04GW of wind capacity over April-July, the first four months of the 2026-27 fiscal year. Solar generation rose by 47pc year on year to 80.87TWh during April-July 2026, while wind generation increased by 5.3pc to 52.07TWh, according to CEA data. The draft also proposes that renewable power plants commissioned after 1 July 2027 have at least 15pc of inverters with grid-forming control. All power conversion systems (PCS) of Bess would also need grid-forming control. The requirements would comply with technical requirements specified in its grid-connectivity regulations, CEA said. It would also be able to change the required percentage of grid-forming capability or ESS capacity from time to time. The CEA has invited comments on the draft until 4 October 2026. By Keertiman Upadhyay Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
South Korea confirms merger of five state-run utilities
South Korea confirms merger of five state-run utilities
London, 3 September (Argus) — Plans to merge South Korea's five state-owned power utilities into a single entity were confirmed by the government today. The government is targeting July 2027 for the launch of the merged entity , sources previously told Argus . The utilities, which have operated separately since they were split from state-owned Kepco in 2001, are preparing for the consolidation through a joint task force. The consolidation is designed to bring the utilities' workforce and assets together to strengthen their ability to support the country's transition towards renewable energy and manage a just transition away from coal. The merged entity will provisionally be called Korea Power Generation. It will have a dedicated division to oversee the just transition from coal-fired generation, alongside a renewable energy division. The government expects the combined structure to increase investment capacity, while joint procurement could improve profitability. But market participants have previously questioned the potential cost savings from joint coal procurement, as buying larger volumes does not necessarily translate into lower prices in the South Korean coal market. They instead see greater benefits in coal supply management. Some expected the merger to bring greater transparency to the South Korean coal market, while others questioned whether reduced competition among buyers would benefit the market. The five utilities currently procure coal individually, with price playing a key role in buying decisions. Following the merger, procurement could put a greater emphasis on supply security and fuel quality , market participants said. Further discussions on the merger are due to take place on Friday, sources told Argus . By Dayu Park HQ location of S Korea's state-owned utilities Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
Frontieras, Western Fuels eye Wyo. coal-to-fuel plant
Frontieras, Western Fuels eye Wyo. coal-to-fuel plant
Houston, 1 September (Argus) — US-based energy and technology company Frontieras North America signed a memorandum of understanding with Western Fuels, owner and operator of Wyoming's Dry Fork mine, to develop a coal-to-fuel plant at the facility. Under the memorandum, the companies established a framework to negotiate the terms of a ground lease for the proposed conversion project to be developed at the mine. Frontieras would use processing technology designed to convert Dry Fork's sub-bituminous coal into liquid fuels including ultra-low-sulfur diesel (ULSD). Through this partnership, Western Fuels would purchase some of the ULSD produced at the site for its mining and transportation operations. Frontieras would use Western Fuel's railway infrastructure to ship products made at the new facility. A coal-feedstock supply agreement would have the Dry Fork mine initially supply an estimated 2.7mn short tons (st)/yr (2.45mn metric tonnes) of coal and about 5.4mn st/yr upon completion of the project. "We are looking ahead to determine opportunities that expand this relationship across the full Western Fuels cooperative — broadly serving our member utilities and their communities while fulfilling our mission," Western Fuels chief executive Adam Anderson said. The companies have not disclosed financial details or details of the project's construction. The Wyoming project follows Frontieras' announcement in January about its plan to develop a $850mn coal-to-fuel plant in West Virginia. Output from Dry Fork in April-June rose to 1.08mn st from 1mn st a year earlier, US Mine Safety and Health Administration data show. By Matt Martin Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
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