India's Adani eyes 10GW nuclear capacity by 2035

Spanish Market: Electricity
24/06/26

India's Adani Group plans to develop 10GW of nuclear power capacity by 2035 as part of a broader push to build an integrated energy platform spanning thermal, renewable, hydroelectric, gas-based and transmission assets.

The plan would be one of the most ambitious private-sector moves into India's nuclear power industry and comes as the government seeks to widen private participation in nuclear generation to help meet rising electricity demand and long-term decarbonisation goals.

Adani Power in February incorporated wholly owned subsidiary Adani Atomic Energy (AAEL), whose stated business is to generate, transmit and distribute electricity derived from nuclear and atomic energy.

"Our entry into nuclear energy through AAEL is another confident step towards securing India's long-term energy future," group chairman Gautam Adani said at the company's annual general meeting on 24 June.

Additional details, including potential project locations, reactor configurations and grid integration plans, were not disclosed.

The group plans to invest more than 2 trillion rupees ($23bn) over the next five years to expand its power generation portfolio to 45GW. The expansion will span thermal, renewable, hydroelectric and pumped-storage assets, alongside investments in transmission and distribution infrastructure.

Adani Power has 18.33GW of operating capacity and 23.72GW of locked-in capacity, taking its target capacity to 42.05GW by the 2031-32 financial year ending on 31 March, data released in early June show. Its project pipeline accounts for around 30pc of India's projected additional coal-based capacity requirement by the 2034-35 financial year, the company said.

The nuclear target aligns with India's plans to increase installed nuclear capacity to 100GW by 2047 from around 8.8GW currently. If achieved, Adani's planned capacity would account for around one-tenth of the country's long-term nuclear target. Nuclear power accounted for about 3pc of India's electricity generation in the 2024-25 financial year, based on government data compiled by the Central Electricity Authority (CEA).

The group is simultaneously expanding its hydroelectric and pumped-storage portfolio, including projects in neighbouring Bhutan through a partnership with Druk Green Power, Adani said. The companies agreed last year to jointly develop up to 5GW of hydropower and pumped-storage capacity, including the 570MW Wangchhu hydropower project.

The company is also expanding into adjacent energy sectors. Adani highlighted growth plans for city gas distribution and piped natural gas infrastructure, while its data centre business is targeting 3GW of capacity by 2030 to support rising demand from digital infrastructure and artificial intelligence applications.

By Keertiman Upadhyay

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23/06/26

Australia’s Queensland budgets $3.6bn in energy spend

Sydney, 23 June (Argus) — Australia's Queensland state government has earmarked A$5.2bn ($3.6bn) for power station maintenance and new transmission lines in its 2026-27 budget, as part of its Energy Roadmap plan. The Liberal National Party (LNP) government added A$1.8bn in funding to its electricity maintenance guarantee over the next five years. This builds on a A$400mn investment towards overhauls at the Callide C and Tarong coal-fired power plants, and the Wivenhoe pumped hydro station in 2025-26, the government said. The state allocated an additional A$3.2bn towards its A$13.9bn CopperString transmission project , which will link the national electricity market with the mining city of Mount Isa in the state's northwest. Its eastern link is expected to reach commercial operations by 2032. Queensland also earmarked A$501mn for the A$2.5bn Gladstone transmission project to reinforce central Queensland's energy grid. The state government expects to receive A$4.7bn in coal royalties in 2025-26, A$6.9bn in 2026-27 and A$6.3bn in 2027-28, budget papers show. Coal royalties were suppressed in 2025-26 due to lower global coal prices, the government said. Hard coking coal accounted for around 54.7pc of the state's total coal export value in 2025, followed by semi-soft coking coal at 25.3pc and thermal coal at 19.9pc. The US-Iran war increased global demand for thermal coal due to the disruption of gas supply from the Middle East, pushing premium thermal coal prices up from $117/t in February to $142/t in early April, the government said. It expects thermal coal prices to moderate over the coming quarters. The budget did not alter the state's coal royalty regime, which is the highest in the world . The Queensland Resources Council called on the government to reduce its royalty settings in a statement on 23 June. Argus assessed hard coking coal fob Australia at $199.60/t and premium hard low-volume fob at $243/t on 22 June. The Queensland government expects coking coal sales to be supported by demand from India and Vietnam. LNG exports from Queensland rose to a record 24mn t in 2024-25 and are expected to be similarly strong in 2025-26, the government said. LNG shipments from Gladstone rose on the year in May to 1.93mn t. Queensland expects to receive A$1.1bn in petroleum royalties in 2025-26, A$1.9bn in 2026-27 and A$1.2bn in 2027-28, which primarily come from LNG. The state government also added A$146mn to accelerate the extraction, processing and export of critical minerals and drive new investments into projects and infrastructure, it said. The current LNP administration has committed to keep state-owned coal-fired power plants operating for longer than the previous Labor administration. By Emma Partis Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

Indonesia speeds up medium-CV coal purchases

23/06/26

Indonesia speeds up medium-CV coal purchases

Manila, 23 June (Argus) — Indonesia's energy ministry (ESDM) has accelerated the signing of medium-rank coal supply contracts for state-owned coal-fired power plants located on the Java grid to address rolling blackouts experienced in the region over the the past two weeks, an ESDM official told Argus on 22 June. Coal deliveries to power plants remain consistent, but the shipments are composed mainly of lower-rank coal which has resulted in power plants operating at a reduced capacity due to coal specification mismatches compared with the requirements of the plants, ESDM said. The rankings classify coal based on their content and characteristics. To address this, ESDM has created a cross-sector procurement team to ensure that there is adequate supply of coal with a calorific value (CV) of GAR 5,200 kcal/kg being delivered to coal-fired plants in the region, the ESDM official said. Shipments of medium-rank coal have already been secured from coal mining companies, including large-scale producers Kaltim Prima Coal, Indo Tambangraya Megah (ITMG), and state-owned producer Bukit Asam, the official said. The coal will be used for blending with lower-grade coal to improve coal-plant firing and restore output to boilerplate capacity. The plants identified with shortages of GAR 5,200 kcal/kg coal include Pelabuhan Ratu, Lontar, Labuan, Suralaya units 1 to 8, Jawa 7, 9 and 10, Indramayu, Paiton units 1, 2, and 9, Rembang, Pacitan, and Tanjung Awar-Awar, the official added. Meanwhile, state-owned utility PLN is already working on reconnecting two baseload independent power plants (IPPs) in Cilacap and Pancitan that went off line due to technical issues, it said. The disconnection of the power plants from the grid, along with the de-rated output of coal plants due to the burning of lower-grade coal, resulted in a temporary dip in power supply, with the power deficit reaching 2GW, PLN said. This prompted PLN to implement load shedding to ensure grid stability, resulting in rolling blackouts. One of the power plants has already been reconnected to the grid over the weekend and the remaining power plant is expected to come on line within the week, PLN said. By Antonio delos Reyes Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

Japan's Shikoku resumes coal-fired unit at Tachibanawan

22/06/26

Japan's Shikoku resumes coal-fired unit at Tachibanawan

Tokyo, 22 June (Argus) — Japanese power utility Shikoku Electric Power resumed operations at the trouble-hit 700MW Tachibanawan coal-fired unit in Tokushima prefecture in western Japan today, after it completed repairs. The utility was forced to shut down the plant on 13 May after a conveyor transporting coal from the storage silo to the boiler became inoperable. Shikoku planned to resume the unit in late June. Restoration work including the removal of coal that had flowed into the conveyor and the repair of damaged areas, has been completed, the company said on 22 June. Japan plans to add around 8.9GW of thermal capacity in the week to 28 June, with the addition of 15.3GW outstripping the closure of 6.4GW, according to Argus ' survey based on a notice by the Japan Electric Power Exchange. This is largely because the country's power demand has been increasing gradually given a rise in temperature levels. Power demand averaged at 90GW in the week to 21 June, up by 5pc from a week earlier, according to nationwide transmission system operator the Organisation for Cross-regional Co-ordination of Transmission Operators (Occto). The rainy season across all regions in Japan started on 21 June. The season, during which solar output is expected to fall, typically creates humid rainy weather that raises power demand for cooling. Shikoku consumed 2.4mn t of coal in the April 2025-March 2026 fiscal year, 3.6pc lower compared with a year earlier, according to the firm's latest financial results released at the end of April. By Reina Maeda Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

El Nino to push Brazil thermal output into 2027

19/06/26

El Nino to push Brazil thermal output into 2027

Sao Paulo, 19 June (Argus) — The El Nino climate pattern could extend Brazil's 2026 dry season and force it to need more thermoelectric output to support peak demand into 2027. Brazil's dry-weather season usually lasts from April through October, often straining its power grid since around 55pc of Brazil's power comes from hydroelectric plants, according to energy research bureau Epe. US meteorological agency NOAA declared El Nino conditions on 11 June and expects the pattern to be stronger than usual by the end of 2026, when most regions in Brazil re-enter their rainy period. Stronger El Nino conditions do not translate into stronger impacts, but rather "significantly tilt the odds in favor of expected regional outcomes", it said. El Nino conditions in Brazil historically bring severe droughts in the northeast and north, while the south tends to face extreme rainfall and flood risks. Meanwhile, the southeast and center-west — which account for about 70pc of Brazil's total hydroelectric storage and generation capacity, according to climate firm Climatempo — usually experience irregular rainfall, increased temperatures and longer dry-weather seasons. Thermoelectric generation increases during dry seasons to support peak demand, with mostly natural gas-fired plants providing power. LNG imports also tend to increase , reflecting demand fluctuations as well as Brazil's gas production and infrastructure bottlenecks. Power grid operator ONS estimates total hydropower reservoir levels to reach 81-125pc of the long-term average by November, when the El Nino is set to intensify. Despite that being 5.9-14.5 percentage points higher than levels in the same period a year before, the El Nino could delay the rainy summer pattern into 2027, large power consumers association Abrace's power director Victor Iocca said. With expected heatwaves driving power consumption, reservoirs could deplete faster than usual, requiring more thermal dispatches from November-March. But anticipated thermoelectric output to protect water levels seems "premature" to forecast in the early days of El Nino, Iocca said. The current criteria for preventive thermal output would only add 0.4pc of water levels back into reservoirs, according to power trading firm Delta Energy's vice-president Luiz Fernando Vianna. Brazil is aiming for a less inflexible gas-to-power grid to reduce its dependency on fossil fuels and more expensive sources, but the El Nino could stress the gas pipeline grid with larger on-spot generation requests , specially following the latest power reserve capacity auction results. By Maria Frazatto Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

Japan's Cosmo Energy mulls LNG-fired power plant

19/06/26

Japan's Cosmo Energy mulls LNG-fired power plant

Osaka, 19 June (Argus) — Japanese energy firm Cosmo Energy is considering building a gas-fired power plant, given that domestic electricity demand is projected to continue rising. No details of the project framework have been decided. The company unveiled the considerations in its business plan to 2035, which was released on 18 June. The firm is mulling a gas-fired power plant while aiming to develop its renewable energy capacity, including wind and solar. LNG-fired generation can counter imbalances in renewables output. The firm aims to raise renewable capacity to 490MW by the April 2028-March 2029 fiscal year, up from 364MW in 2025-26. It also plans to increase power sales by 35pc to 3.1TWh over the same period. But power sources need to balance economic viability with decarbonisation, without being limited to green energy, the company said. Cosmo is also looking to expand its upstream exposure to natural gas beyond its traditional crude oil business. Details, such as location and timeline, have yet to be decided as the plan remains under consideration. The company may explore such opportunities in the UAE, where it plans to expand oil production . It remains unclear whether Cosmo will also move into liquefaction and LNG trading, even if it expands into upstream gas production and gas-fired generation. Fellow energy firm Idemitsu decided in March to invest in MidOcean Energy, an LNG company backed by US investment firm EIG, with the possibility of engaging in LNG trading. By Motoko Hasegawa Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

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