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Source: Central Electricity Authority
In 2023-24, total electricity consumption in India was 1,543 TWh (terawatt hour). Total electricity consumption increased fourfold since 2001 and over 35-fold since 1947. In 2023-24, industrial electricity consumption accounted for about 42 percent of total electricity consumption followed by domestic consumption that accounted for about 24.3 percent. Agricultural consumption accounted for about 16.5 percent, commercial consumption about 8 percent and railway traction about 2 percent in 2023-24.
Domestic consumption, which accounted for about 10 percent of total consumption until 1980, has increased its share to nearly 25 percent since then. Increase in incomes as well as the increase in adoption of electrical appliances, programmes to electrify poor households, increase in generation and transmission capacity are among the many drivers behind the increase in the share of domestic consumption. The share of industrial consumption, which was at 70-75 percent until the 1980s, has fallen to about 40 percent in 2023-24. Reduction in state-driven industrialisation policies, increase in the share of the service sector in economic activity, along with efficiency in energy consumption by industries, are among the reasons for the reduction in the share of electricity consumption by the industrial sector. The share of electricity consumption by the agricultural sector has increased from about 6 percent in the 1960s to about 16 percent in 2023-24. The peak share of agricultural electricity consumption was in the 1980s and 1990s, when it accounted for about 25 percent of total electricity consumption. Increase in electrification of villages for irrigation, along with policies to subsidise electricity consumption for food production, to achieve the goal of food security, are among the many drivers of an increase in the share of agricultural electricity consumption. The share of electricity consumption by the commercial segment has increased from 4-5 percent in the 1960s to about 8 percent, and the share of railway traction in electricity consumption has declined from about 3-4 percent in the 1960s to about 2 percent in 2023-24.
In 2001-24, overall electricity consumption in India grew by an annual average of about 6 percent. The fastest growth in this period was by the commercial segment, which grew at an annual average of over 7 percent. The slowest growth was in agricultural consumption, which grew at an annual average of about 5 percent. Double-digit electricity consumption growth was recorded in the period 1980-2000. Overall electricity consumption grew at an annual average of over 13 percent in this period with domestic electricity consumption recording an annual average growth of over 20 percent followed by the agricultural sector which recorded an annual average growth of over 16 percent. The slowest annual average growth in electricity consumption was recorded by the industrial segment at about 7 percent from 1980 to 2000.
In the decade ending in 2012, electricity consumption grew at an annualised rate of 7.7 percent, which fell to about 7 percent in the decade ending in 2024. In the two decades, industrial electricity consumption growth fell from an annualised growth rate of about 8 percent to about 6 percent, while commercial electricity consumption growth fell from an annualised rate of over 10 percent to about 7 percent, respectively. Domestic and agricultural consumption, whose tariff is subject to regulation and subsidies, recorded an increase in consumption growth rates in the two decades. In the decade ending in 2012, domestic consumption grew by an annualised rate of about 7.7 percent while it grew by an annualised rate of 8 percent in the decade ending in 2024. Agricultural consumption which grew by an annualised rate of about 5.6 percent in the decade ending in 2012, grew by about 6 percent in the decade ending in 2024. Faster growth in electricity consumption by sectors where the tariff is subject to regulatory limits and subsidies could mean greater upward pressure on tariffs in the unregulated sectors. An increase in the electricity tariff for industrial and commercial consumers could reduce the competitiveness of India’s product and service exports.
Electricity Transmission
India’s power transmission sector is grappling with supply side constraints that is causing a significant delay in completion of ongoing projects. The Electric Power Transmission Association has written to the power ministry seeking a level-playing field in procurement policy to address the disparity in imports of HVDC (high voltage direct current) transmission equipment from neighbouring countries. The regulations are especially hurting HVDC projects since the technology and equipment is available only in a handful of countries, including China. Central Electricity Regulatory Commission has acknowledged that constraints in HVDC component supply are significantly impacting project costs, thereby justifying the higher L1 bids relative to levelised norms. The recently concluded bids for two HVDC projects with an implementation timeframe of 54 months shows that it required 19 months to only conclude the bids. According to Electric Power Transmission Association, addressing the disparities is essential to ensure the synchronized development of generation and transmission infrastructure. It also suggested that transmission companies to be exempted from the restrictions until December 2030 so that procurement and subcontracting of critical HVDC components from global vendors can happen in a seamless manner.
Power Grid Corporation of India Ltd (PGCIL) announced the acquisition of MEL Power Transmission Ltd, a special purpose vehicle (SPV), from PFC Consulting for INR5.58 billion (bn) (US$63.74 million (mn)). PFC Consulting is a wholly owned subsidiary of the Power Finance Corporation. The SPV has been tasked with developing a transmission system to evacuate power from Mahan Energen’s power generation plant in Madhya Pradesh. The project will be executed on a BOOT (Build, Own, Operate, Transfer) basis.
In a significant step toward strengthening the power network in Arunachal Pradesh, Power Grid Corporation of India Ltd (PGCIL) has completed the 220 kilovolt (kV) double circuit Kathalguri-Namsai transmission system five months before its scheduled deadline. The project, carried out under the Tariff-Based Competitive Bidding (TBCB) model, enhances the reliability of electricity supply across the region. Stretching 71 kilometre (km), the new line connects the Assam gas-based power plant operated by NEEPCO at Kathalguri to a modern 220 kV gas-insulated substation (GIS) at Namsai in Arunachal Pradesh.
Discom Reform
Tata Power plans to bid for two electricity distribution companies (discoms) in Uttar Pradesh (UP) —Dakshinanchal Vidyut Vitran Nigam and Purvanchal Vidyut Vitran Nigam—once tender documents are released. This move supports Tata Power’s goal to grow its transmission and distribution (T&D) business, which brings in most of its revenue and a large share of its profits. Currently, Tata Power handles electricity supply in Mumbai, Delhi, Ajmer, and Odisha, serving 12.5 million customers. It aims to expand its customer base to 40 million within the next five years. UP has five discoms, and the government seeks private sector involvement in two—Dakshinanchal and Purvanchal. The state’s goal is to cut losses and enhance efficiency in these discoms. Most likely, the government will choose a public-private partnership, with private companies holding a majority stake. Tata Power plans to exit Tata Projects, best known as the contractor that built India’s first parliament building after independence, as it wants to focus on its main businesses.
Demand Growth
Tamil Nadu Power Distribution Corporation Ltd (TNPDCL) reported a significant increase in the city’s power demand. This surge is attributed a rise in air conditioner usage across the city because of prevailing sultry weather conditions. The city’s power demand, which was around 3,300 megawatt (MW) until May, rose by 15 percent to 3,800 MW in the past three days. The overall power consumption increased by 10 million units (MU) from the average 70 MU recorded until May. Chennai’s all-time high-power demand was 4,769 MW. Across the state too, power demand increased despite rain in the southern districts.
Andhra Pradesh state is expected to witness high power demand in the coming months from June to November, ranging between 218 MU and 235 MU per day. The southern state logged a peak power demand of 12,600 MW on 13 May and added that average daily consumption is reaching around 228 MU. Further, the state directed the power utilities to remain on high alert in view of the anticipated pre-monsoon thunderstorms and gusty winds. In case of any disruptions to power supply, the state emphasised the need for immediate restoration measures without delay. The state instructed all discoms to set up 24x7 control rooms for round-the-clock monitoring, emergency response, and prompt grievance redressal.
The power demand in Telangana has reached a record high of 17,162 MW this year, increasing by 9.8 percent compared to last year. As per the state Energy Department, the demand is also expected to increase in the coming days and may touch over 18000 MW. Energy department estimated that the power demand may be 31,808 MW by 2034 – 2035.
Seventeen villages nestled among nearly inaccessible mountains and dense forests in Maoism-hit Mohla-Manpur-Ambagarh Chowki district of Chhattisgarh have got electricity from the supply grid for the first time. About 540 families will benefit from the electrification, which has been done at INR30 mn (US$0.34 mn) under the Mukhyamantri Majratola Vidyutikaran Yojana. Due to the difficult terrain, reaching these areas was extremely challenging amid the Maoist threat. Providing the electricity supply through the grid was no less than a mission in these villages. Celebrations broke out in the villages— Katuljhora, Kattapar, Bodra, Bukmarka, Sambalpur, Gattegahan, Pugda, Amakodo, Petemeta, Tatekasa, Kundalkal, Raimanhora, Nainguda, Metatodke, Kohkatola, Edasmeta and Kunjakanhar— after they were connected to the power grid recently. Of the 540 families in these 17 villages, 275 have got electricity connections so far. The work to provide the power supply to the remaining households is underway.
Generation
India’s generation capacity addition is expected to grow by almost 30 percent year-on-year (Y-o-Y) to 44 gigawatt (GW) in FY26 with almost one-fifth of the capacity being thermal powered. It is expected that the generation capacity addition to reach an all-time high of around 44 GW in FY26, a sharp step up from the previous high of 34 GW in FY25, with the overall installed power generation capacity reaching close to 520 GW by March 2026.
As per Punjab Power Ministry, Union Power Ministry approved the setting up of three additional 800 MW power generation units in the state. The Punjab government demanded an increase in the existing power generation capacity of Ropar thermal plant, stating that while Punjab has its own coal mines, the Centre’s condition of not transporting coal beyond 1,000 km is creating difficulties in expanding the capacity of these thermal plants. The state demanded prompt fulfilment of the 1,000 MW power from the Centre in view of the paddy season. Currently, Punjab state is receiving 275 MW power from the central pool.
Regulation and Governance
Anticipating a record power demand of 9,000 MW this summer, the Delhi government has instructed power discoms to step up preparedness across key areas, particularly during extreme weather disruptions. Delhi’s power demand had peaked at 8,656 MW last year. With urban expansion and rising heat conditions, this summer’s peak is projected to breach the 9,000 MW mark. Discoms have been directed to focus on four fronts: demand forecasting, supply arrangement, emergency response, and fault management. Discoms have reportedly secured power through long-term, medium-term, and short-term contracts based on load projections. In case of sudden surges, additional power will be procured through power exchanges. To improve forecasting accuracy, the Delhi government has asked discoms to adopt AI and Machine Learning tools to better predict peak demand periods and manage load accordingly. The use of predictive technology is expected to support better supply planning and the timely deployment of resources. Emergency quick response teams (QRTs) are also being kept on standby to manage outages, especially during weather events like thunderstorms and dust storms. Recent severe weather events tested the resilience of Delhi’s power infrastructure. Discom BSES reported damage to nearly 60 poles and 10 transformers or substations across south, west, east, and central Delhi. Downed trees blocked access for repair crews, delaying restoration in several areas. Tata Power Delhi Distribution Ltd (DDL) reported that 13 high-tension and 43 low-tension poles were broken, and 187 service lines were impacted in areas like Civil Lines, Wazirabad, and Burari. Nearly 257 trees fell, damaging lines and obstructing roads. Despite the widespread disruption, discoms activated emergency protocols immediately, coordinated with civic agencies for debris clearance, and restored power in phases using insulated tools and safety gear.
China
The recent deal between the United States (US) and China to pause trade hostilities for 90 days will likely spur renewed activity throughout China’s mammoth manufacturing sector, with repercussions for the country’s energy needs. The share of clean power sources within China’s overall electricity generation mix will take a hit as factory production picks up across the country. Clean power sources accounted for a record 39 percent of China’s electricity supplies during the first quarter of 2025, Ember shows data, helped by an 18 percent jump in clean electricity output from the same period in 2024 to 950 terawatt hour (TWh).
Other Asia Pacific
According to Pakistan finance ministry, the country will allocate 2,000 MW of electricity in the first phase of a national initiative to power bitcoin mining and AI data centres. The allocation is part of Islamabad’s plans to use its surplus electricity to bitcoin mining and AI data centres. Pakistan’s energy sector is grappling with challenges, including high electricity tariffs and surplus generation capacity.
Africa & Middle East
Syria has signed a memorandum of understanding (MoU) with a consortium of international companies led by Qatar’s UCC Holding to develop major power generation projects with a foreign investment valued at about US$7 bn. Construction is expected to begin after final agreements and financial close, and is targeted to finish within three years for the gas plants and less than two years for the solar plant. Once completed, the projects are expected to provide over 50 percent of Syria’s electricity needs. After 14 years of war, Syria’s electricity sector has been suffering from severe damage to its grid and power stations, aging infrastructure, and persistent fuel shortages, generating only 1.6 GW of electricity, down from 9.5 GW before 2011. Reconstructing the power sector is expected to cost around US$11 bn and the new administration is betting on the private sector shouldering the burden, underlining a shift from the state-led economic policies of the Assad era.
North & South America
According to the US Energy Information Administration (EIA), power-hungry data centers that provide computing power for artificial intelligence and crypto currency will push US electricity consumption to record highs in 2025 and 2026. The EIA projected power demand will rise to 4,193 billion kilowatt hour (kWh) in 2025 and 4,283 billion kWh in 2026 from a record 4,097 billion kWh in 2024. In addition to data centers, American homes and businesses are expected to use more electricity for heat and transportation. The EIA forecast 2025 power sales will rise to 1,517 billion kWh for residential consumers, 1,474 billion kWh for commercial customers and 1,055 billion kWh for industrial customers. Those forecasts compare to all-time highs of 1,509 billion kWh for residential consumers in 2022, 1,434 billion kWh in 2024 for commercial customers and 1,064 billion kWh in 2000 for industrial customers.
The middle section of the US and Canada could have a shortfall of electricity this summer if higher-than-normal forecasted temperatures drive up demand as a changing mix of power supplies increases reliability risks, the organization overseeing the area’s grid said. Electricity demand in the US and Canada has grown by 10 GW since last summer -- a more than doubling of the previous year's increase -- while fossil-fired power supplies retire and solar power additions surge, the North American Electricity Reliability Corporation said.
Brazilian power firm Eletrobras, Latin America’s largest utility by generating capacity, posted a 354 million reais (US$62.8 mn) net loss for the first quarter, compared to a 331 mn-reais profit a year earlier. Adjusted earnings before interest, taxes, depreciation and amortization (EBITDA), adapted for local regulatory rules, came in at 5.38 bn reais in the three-month period to the end of March, down 4.1 percent from a year earlier.
Europe & Russia
Spain’s Energy Minister Sara Aagesen urged private electricity companies to speed up sharing information needed to identify the causes of the worst ever blackout to hit Spain and Portugal. More than a month after one of Europe’s biggest electricity system collapses left around 60 million people in the two countries without power, the cause has yet to be determined and the blame game has intensified. The European network of transmission system operators ENTSO-E has also launched an inquiry, while a Spanish court is investigating whether a cyber-attack caused the blackout. Spanish lawmakers are conducting separate probes. Spanish grid operator Red Electrica insists the transmission grid it manages was working without issues before the blackout.
The Czech anti-monopoly office UOHS has started an investigation into a potential cartel agreement among three major Czech energy suppliers, it said. The case followed up on an initial probe last year in a case when UOHS inspected premises of electricity producers CEZ, EPH and Veolia Energie, over a government auction for state aid for building power plants.
European Union (EU) must enforce common market rules to integrate the Iberian peninsula’s power grid into wider Europe, overcoming France’s reluctance to add interconnections, Portugal said, after a massive blackout hit the peninsula. The blackout, which started in Spain and also left mainland Portugal without electricity on 28 April, could have been less crippling had the two countries had more interconnections to resume power supplies rather than just relying on their own power plants. Works to strengthen an existing interconnector between France and Spain are expected to wrap up this year, while a new underwater power line spanning the Bay of Biscay is set to be completed by 2028. Although French grid operator RTE has studied the feasibility of building two additional interconnections with Spain over the Pyrenees, Portuguese Energy Minister Maria da Graca Carvalho said they are not part of France’s new plan until 2035.
An abrupt loss of power generation at a substation in Granada, followed by failures seconds later in Badajoz and Seville, triggered an unprecedented blackout across Spain and Portugal on 28 April, Spain’s Energy Minister Sara Aagesen said. Aagesen said that the three initial incidents, whose cause has yet to be determined, led to a generation loss of 2.2 GW of electricity, which triggered a series of grid disconnections. Several investigations are looking into the power outage, but it is the first time Spanish authorities have pointed to a specific origin. Establishing the cause of the outage will take time and there will likely be no simple answers to what appears to be a complex issue, Aagesen said.
12 June: As the Centre and states discuss rationalising the Goods and Services Tax (GST) framework in the country, the Union Minister of Road Transport and Highways has suggested reducing the GST rate on crude ethanol. Currently, ethanol used under the Ethanol Blended Programme (EBP) attracts a concessional GST rate of 5 percent, while crude ethanol attracts a GST rate of 18 percent. The minister has urged to reduce the current GST rate on the latter to 5 percent. Gadkari has argued that the higher taxation on crude ethanol is dampening its demand. Despite 400 fuel outlets offering 100 percent ethanol, consumer uptake remains significantly low, and this can be reversed with a more favourable tax structure. The current GST system comprises four slabs: 5 percent, 12 percent, 18 percent, and 28 percent. While most items are taxed under the 5 percent slab, the bulk of the tax collection comes from the 18 percent category. Gadkari’s suggestion to lower the GST on crude ethanol highlights India’s broader energy and mobility goals.
17 June: The scale of a natural gas leak from a rig in eastern Assam’s Sivasagar district has led the Oil and Natural Gas Corporation (ONGC) to contact foreign experts to contain it. More than 1,500 people from villages around the rig in the district’s Rudrasagar field have been evacuated to safety after the leakage occurred four days ago. Chief Minister Himanta Biswa Sarma said the State’s Chief Secretary, Ravi Kota, discussed the matter with the Secretary in the Ministry of Petroleum and Natural Gas, and the Chairman of the oil exploration major, who is expected to visit Sivasagar soon.
17 June: The coal ministry said it has allocated a total of 200 coal blocks so far. The allocation for the Marwatola-II coal block in Madhya Pradesh to Singhal Business Pvt Ltd reaffirms the government's commitment to sectoral reforms, fostering private participation, and bolstering national self-reliance in coal production, it said. Over the past several years, the coal ministry has ushered in a suite of transformative reforms, from the advent of commercial coal mining and the rollout of a single-window clearance system to the adoption of digital monitoring and governance tools. Prime Minister Narendra Modi in 2020 launched the auction process for 41 coal blocks for commercial mining, a move that opened India’s coal sector for private players.
16 June: The 12th round of the commercial coal auction witnessed 27 companies, including Damodar Valley Corporation (DVC), NLC India and Jindal Steel & Power Ltd (JSPL), placing bids for 11 blocks, the coal ministry said. The latest round was launched in March this year. The nominated authority opened the bids for the 12th round of commercial coal blocks’ auction (excluding 6 underground coal blocks). Bids have been received for 11 coal blocks out of the total 22 blocks.
12 June: The coal output in the country is expected to decline further in June as demand remained muted across several regions during the pre-monsoon season, according to Nuvama Research report. The report highlighted that India’s major coal producer, Coal India Ltd (CIL), has started FY26 on a weak note with sales volumes falling about 4.7 percent year-on-year during the April-May 2025 period. The coal ministry data shows that overall power demand during April-May 2025 fell 1.6 percent YoY (year-on-year), impacting coal demand across many regions. In addition to this, rising volumes from captive and commercial coal mines have further dented Coal India Ltd (CIL)’s market share.
13 June: In a move aimed at expanding its footprint into Mumbai, MSEDCL (Maharashtra State Electricity Distribution Company Ltd) has filed an application before the Maharashtra Electricity Regulatory Commission (MERC), seeking a parallel licence to distribute electricity across the financial capital. MSEDCL said the petition has been submitted under sections 14 and 15 of the Electricity Act, 2003, along with provisions of the MERC Rules, 2006, and the Electricity Distribution Licence Rules, 2005. The company has urged the commission to grant it permission to supply electricity to key regions in Mumbai -- ranging from Colaba to Mahim, Bandra to Dahisar, Vikhroli to Chunabhatti and Mankhurd, as well as Chena, Kajupada, and Mira Bhayandar Municipal Corporation limits. Currently, power in Mumbai is distributed by three players -- civic utility Brihanmumbai Electricity Supply and Transport Undertaking (BEST), private companies Adani Electricity Mumbai Ltd and Tata Power Mumbai.
12 June: Amid soaring temperatures, Delhi recorded its highest peak power demand of this summer. The real-time figures of the State Load Dispatch Centre (SLDC) showed the peak demand was 8,423 megawatt (MW). Delhi’s peak load had clocked 8,231 MW. It was the first time this year when Delhi's peak power demand had crossed 8,000 MW. This year, the peak power demand of Delhi is expected to cross 9,000 MW. In 2024, the national capital recorded an all-time high peak demand of 8,656 MW. Delhi’s peak power demand crossed 8,000 MW for the first time in 2023. Tata Power Delhi Distribution Limited (Tata Power-DDL) said it successfully met peak power demand of 2,407 MW - without any outages or network constraints.
17 June: The Najafgarh drain canal-top solar power project, recommended by lieutenant governor VK Saxena in April 2023, is set to take off, with power minister Ashish Sood confirming that the plan is currently on the drawing board and is likely to be rolled out soon. Under the project, aimed at setting up solar panels above the Yamuna along its route, the government aims to generate 30 megawatt (MW) of power. The Najafgarh solar power project is likely to be modelled on Gujarat’s canal solar power project, wherein solar panels along the network of Narmada canals generates electricity. The first phase will involve installation of solar plants at six pockets on a six-kilometre stretch between Dhansa border and Ghummanhera, to generate 5 MW power. Similar plants will be set up along other stretches to generate 30 MW power.
17 June: The central government is set to float offshore wind energy tenders totalling 4 GW (gigawatt) in Gujarat and Tamil Nadu. The move forms part of the government’s broader strategy to boost wind energy capacity, backed by a 53 percent increase in the renewable energy budget to INR265.49 billion for 2025–26. The centre is focusing on five key areas to unlock India’s wind energy potential—expansion into new states such as Madhya Pradesh, Telangana and Odisha; leasing 4 GW of offshore wind zones; hybrid integration with solar and storage and investments in artificial intelligence based forecasting and grid upgrades; and domestic manufacturing support.
16 June: A group of solar prosumers in Kerala are challenging the imposition of fixed charges on electricity generated and consumed on-site through their own solar systems. A group of solar prosumers has filed a writ petition before the Kerala High Court challenging the state’s electricity board for imposing fixed charges on electricity generated and directly consumed by prosumers through their own on-grid solar systems. The petition said that while these solar systems remain connected to the Kerala State Electricity Board (KSEB) grid (on-grid), the portion of electricity generated and immediately consumed within the premises belongs solely to the prosumer and does not constitute a supply from KSEB. Imposing fixed charges on this self-consumed energy without any specific provision in the Electricity Act, 2003, or any tariff order approved by the Kerala State Electricity Regulatory Commission (KSERC) is arbitrary, unauthorised, and violative of constitutional and statutory protections.
16 June: The Uttar Pradesh State Industrial Development Authority (UPSIDA) has launched a major green initiative to install solar power plants across 13 industrial zones in the state. This move aligns with the state’s Solar Energy Policy-2022, aiming to reduce energy costs, promote environmental conservation, and cut carbon emissions. UPSIDA said that the government envisions industrial areas not only leading in production but also setting benchmarks in sustainability and clean energy adoption. By developing these “Solar Industrial Zones,” UPSIDA aims to transform key industrial areas into models of eco-friendly growth, helping the state transition toward a cleaner, more sustainable future while enhancing the self-sufficiency of its industrial sector.
15 June: Karnataka increased its wind power capacity by 1,331.48 megawatt (MW), securing the State first place in the country for its wind power capacity addition in the financial year (FY) 2024 – 25. The State’s installed wind power capacity more than the combined capacity of countries like South Africa, Portugal, and New Zealand, and is comparable to that of Sweden and Australia, claimed the officials of the Energy Department. Karnataka was followed by Tamil Nadu, which added 1,136.37 MW, and Gujarat, which added 954.76 MW during the FY. The State is preparing to implement 17 gigawatt (GW) of wind power projects, with over 5 GW planned under the Renewable Energy Cluster Programme. As the fourth largest wind power generator in the world, India currently has an installed wind capacity of 51.5 GW. The Ministry of New and Renewable Energy (MNRE) plans to increase this to 100 GW in the next few years.
13 June: The decline in power demand, together with continued renewable capacity additions the last year, caused the share of renewable energy generation in India jump to 17 percent in May and to 19 percent in first 10 days of June — compared to 13 percent/14 percent in May/June last year, respectively, an HSBC report showed. Large base and excess rainfall cause decline in power demand. Power demand/peak demand declined 4 percent/7 percent in May and declined 1 percent/1 percent in the first 10 days of June, respectively. Owing to the must-run status of renewables, thermal plants had to back down reducing the plant load factor (PLF) to 65 percent in May (versus 72 percent last year). Government is backing storage. To solve the intermittency issue of renewable energy, batteries are critical to control curtailment, improve renewable energy offtake, and improve efficient use of existing coal plants.
13 June: In a strategic push towards green energy, Coal India Ltd (CIL) has launched a new subsidiary—CIL Rajasthan Akshay Urja Limited—in partnership with Rajasthan Rajya Vidyut Utpadan Nigam Limited (RRVUNL), the state power generation company. This move marks Coal India’s significant entry into the renewable energy sector in Rajasthan. The newly formed joint venture will see Coal India holding a 74 percent stake, while RRVUNL will own 26 percent. The company was officially incorporated on June 12, as confirmed the of corporate affairs ministry. This collaboration reflects Coal India’s intent to diversify its portfolio and contribute to India’s renewable energy goals, in alignment with national clean energy targets.
11 June: India’s total renewable energy capacity grew 17.13 percent year-on-year to 226.74 gigawatt (GW) in May, Union Minister Pralhad Joshi said. The renewable energy capacity has surged 17.13 percent year-on-year to 226.74 GW in May from 193.58 GW in the same month last year. Of the total, solar power capacity expanded 31.49 percent to 110.83 GW from 84.28 GW in May 2024. Wind capacity witnessed a rise of 10.49 percent to 51.29 GW against 46.42 GW last year. Joshi said clean energy is shaping India's journey of progress and pride.
17 June: Global oil demand will keep growing until around the end of this decade despite peaking in top importer China in 2027, as cheaper gasoline and slower electric vehicle adoption in the United States (US) support consumption, the International Energy Agency IEA) said. Despite seeing an earlier demand peak for China, the IEA, which advises industrialised countries, stuck to its prediction that global demand will peak by 2029. This view sharply contrasts with that of producer group OPEC (Organization of the Petroleum Exporting Countries), which said consumption will keep growing for much longer. Oil demand will peak at 105.6 million barrels per day (bpd) by 2029 and then fall slightly in 2030, the IEA said. At the same time, global production capacity is forecast to rise by more than 5 million bpd to 114.7 million bpd by 2030. A conflict between Israel and Iran has highlighted the risk to Middle East supplies, helping send oil prices up 5 percent to above US$74 a barrel. Still, the latest forecasts suggest ample supplies through 2030 if there are no major disruptions, the IEA said. Global supply in 2025 will rise by 1.8 million bpd, up 200,000 bpd, the IEA said. This is partly because OPEC+, which groups the OPEC plus Russia and other allies, is raising output. World demand in 2025 will rise by a much lower 720,000 bpd, the IEA said.
17 June: China is continuing to build up crude oil stockpiles as it refines substantially less than what it has available from imports and domestic production. This allows the world’s biggest oil importer to buy lower volumes in coming months as prices surge over Middle East tensions. China’s surplus crude amounted to 1.4 million barrels per day (bpd) in May, the third straight month it has been above the 1 million bpd level. The price of crude oil has spiked since 13 June when Israel launched a series of air strikes against Iran, prompting drone and missile retaliation by Tehran. While the conflict has yet to hit Iran’s crude oil production and export facilities, the heightened risks have seen Brent futures rise almost 6 percent since the close on June 12 to trade around US$73.58 a barrel in Asia.
13 June: United States (US) ultra-low sulfur diesel futures hit the highest level since February, outpacing gains in oil and gasoline as analysts warned that diesel supply is the most exposed to the conflict in the Middle East. Israel launched the biggest ever direct attack on Iran and said the huge wave of airstrikes was only the start of its campaign. Crude oil futures jumped about 7 percent as analysts worried Iran’s response could include a blockade of the Strait of Hormuz, through which a fifth of global oil supplies traverses. Diesel futures jumped even more, surging about 8 percent for their biggest single-day gains since April 2022. Diesel outperformed because the conflict’s biggest impact is expected to be on the supply of medium heavy-sour crude grades, which are better suited for production of distillate fuels, StoneX oil analyst Alex Hodes said.
13 June: Israel’s strikes on Iran have raised the prospect of global oil prices hitting US$100 a barrel. If Tehran seeks to escalate the conflict by retaliating beyond Israeli borders, it could seek to choke off the Strait of Hormuz, the world’s most important gateway for oil shipping. Saudi Arabia, the world’s largest oil exporter, sends some of its crude through the Red Sea pipeline that runs from the Abqaiq oilfield in the east into the Red Sea port city of Yanbu in the west. The Saudi Aramco-operated pipeline has a capacity of 5 million barrels per day (bpd) and was able to temporarily expand its capacity by another 2 million bpd in 2019. It is used mostly to supply Aramco’s west coast refineries. Saudi Arabia also exported 1.5 million bpd of oil from its west coast ports in 2024, including 839,000 bpd of crude, according to analytics firm Kpler data.
17 June: The European Commission proposed a legally binding ban on EU (European Union) imports of Russian gas and liquefied natural gas (LNG) by the end of 2027, using legal measures to ensure the plan cannot be blocked by EU members Hungary and Slovakia. The proposals set out how the EU plans to fix into law its vow to end decades-old energy relations with Europe's former top gas supplier, made after Moscow’s 2022 invasion of Ukraine. First, imports would be banned from 1 January 2026, under any Russian pipeline gas and LNG contracts signed during the remainder of this year. Imports under short-term Russian gas deals - defined as those lasting less than one year - signed before 17 June 2025, would be banned from 17 June next year. Finally, imports under existing long-term Russian contracts would be banned from 1 January, 2028, effectively ending the EU’s use of Russian gas by this date, the Commission said. Hungary and Slovakia, which still import Russian gas via pipeline and have opposed the EU plans, would have until 1 January 2028, to end their imports, including those on short-term contracts. Companies including TotalEnergies and Spain’s Naturgy have Russian LNG contracts extending into the 2030s.
17 June: Germany is not planning to set up a national gas reserve as its recent legislation changing required filling levels for the coming winters will encourage the private sector to ensure supply security, the economy ministry said. Since the energy crisis following Russia’s invasion of Ukraine in 2022, European Union (EU) countries have turned to increased storage to protect against supply disruption. Germany is mainland Europe’s biggest gas consumer and last month German pipeline lobby group FNB proposed a new approach to gas storage, including a permanent national reserve. Germany’s new coalition government aligned domestic rules with anticipated changes to European Union regulations that require gas storage facilities to be 80 percent filled by 1 November to ensure enough supply for the winter, giving more flexibility than the EU’s previous 90 percent capacity filling requirement, among a range of other measures. German utilities operating gas storage facilities include Uniper, the SEFE group, VNG Gasspeicher and RWE.
13 June: China’s annual imports of liquefied natural gas (LNG) are forecast to decline for the first time in three years on weak industrial demand and strong domestic and piped gas supply, according to revised forecasts from five research firms. A decline in imports at the world's top LNG buyer would drive up global supply and drag Asian spot prices, which are down 12 percent so far this year. China’s LNG imports last contracted in 2022 as demand tumbled during the pandemic lockdowns, according to customs data. China imports fell to 20 million metric tons during the first four months of this year, down from nearly 29 million tons in the corresponding period last year, customs data showed. Rystad Energy estimates that gas consumption for the industrial and chemical sectors combined will fall by roughly 1 percent. Australia, China’s top LNG supplier in 2024, shipped 6.38 million tons to China in the first four months of 2025, down 24 percent from a year earlier, according to China customs data.
13 June: Gas transmission system operators of Poland and Ukraine will double the transmission capacity of the interconnector to 12.4 million cubic meters (mcm) of gas a day from the current 6.4 mcm, Ukraine’s energy ministry said. Ukraine has said it wants to import large volumes of US (United States) LNG (liquefied natural gas) via Germany, Greece, Lithuania and Poland ahead of the heating season, after Russian shelling left the country with storage almost empty. Higher volumes will be available via auctions for daily and monthly capacity, with the auction for increased July volumes planned for 16 June, Polish operator Gaz-System said. Gaz-System previously told Reuters that the upgrade of the Hermanowice station would be ready at the end of 2025 or early 2026 and could cost 8 million zloty (US$2.12 million). Naftogaz, Ukraine’s state energy firm, and Polish refiner Orlen have agreed to cooperate in the LNG sector. Naftogaz has already bought 300 mcm of LNG from Orlen. Ukraine said it would import 5.6 mcm of gas from Poland.
13 June: United States (US) natural gas futures climbed about 3 percent, tracking gains in oil prices after Israel launched strikes against Iran, raising worries the conflict could disrupt Middle Eastern oil and gas supplies. Gas futures for July delivery on the New York Mercantile Exchange rose 8.9 cents, or 2.5 percent, to settle at US$3.581 per million metric British thermal units (mmBtu). So far this year, energy firms have pulled a monthly record high of 1.013 trillion cubic feet of gas out of storage during a brutally cold January and added a monthly record high of 497 billion cubic feet (bcf) into storage in May when mild weather kept both heating and cooling demand low, according to federal energy data. The prior all-time monthly injection high was 494 bcf in May 2015.
12 June: Egypt has reached agreements with several energy firms and trading houses to buy 150 to 160 cargoes of liquefied natural gas (LNG), as it ramps up purchases to meet power demands despite strained government finances. The world’s most populous Arab country has endured rolling blackouts over the past two years as natural gas supply fell short of demand. It returned to being a net importer of gas last year, buying dozens of cargoes and abandoning plans to become a supplier to Europe as domestic production tumbled. The LNG deals represent Egypt’s largest ever import purchases and will cost it over US$8 billion at current prices.
12 June: Australia could start imports of liquefied natural gas (LNG) from 2027, based on developments at import terminal projects along its east coast, to address potential supply shortages. The country’s competition regulator has said that the east coast may face a longer-term shortfall amid higher demand and structural decline. Below is a list of four proposed projects being advanced on the east coast, consisting of floating storage and regasification units (FSRUs), which will send gas via pipelines back to the mainland for consumption. The Port Kembla Energy Terminal is already commissioned and plans to import around 2 million metric tons of LNG yearly. The project’s commercial operations date has been delayed to 2027 from 2026 after operator Squadron Energy extended the sub-charter of the FSRU, Hoegh Galleon, to Egypt’s EGAS until end-2026, according to the company. The terminal is already connected to gas and electricity distributor Jemena’s Eastern Gas Pipeline, according to the Australian Energy Market Operator. The proposed terminal, pending a final investment decision, will be built by converting a 145,000 cubic meters LNG carrier to an FSRU. Construction is expected to be completed by the end of 2026, with the first gas to flow into the system by mid-2027, Venice Energy said. The Australian government has cleared the construction of Viva Energy Group’s LNG terminal in Geelong, the company said. The terminal will use an FSRU with a 7 kilometre (4.35 miles) pipeline connecting it to Victoria, with a capacity of 160 petajoules or about 2.9 million tonnes per year. Vopak has started talks with gas suppliers and offtakers for its LNG import terminal project in Victoria and expects to make a final investment decision in 2026-2027. It aims to start terminal operations in 2029. Vopak is seeking an FSRU with a capacity of 170,000 cubic meters to regasify LNG, and gas would be transported to Victoria through a 19 km underwater pipeline.
16 June: China sent a rare shipment of at least three cargoes of coking coal to processors in Indonesia’s Sulawesi in May, encroaching on a market typically dominated by supplies from Australia and Indonesia. The world’s biggest importer of coking coal, China is not a major exporter of the steelmaking fuel, and has exported it to Indonesia only three times since the start of 2024, monthly Chinese customs data shows. Shanxi Coking Coal Group sold coking coal to China Risun Group, which was later exported to Indonesia. Risun runs one of the largest coke-processing plants in Indonesia’s Sulawesi region. In the longer term, as China’s slowing steel industry could free up supply of coking coal, turning it into a regular export product, an executive at Chinese trading house Winsway said. China exported 78,030 metric tonnes of coking coal to Indonesia in April, the first shipment since last July. Coke processing plants in Sulawesi have emerged as a supply hub for metallurgical coke - a raw material used by steelmakers, boosting demand for coking coal, which is used to make the coke.
16 June: Guatemala has launched a tender to contract 1500 megawatt (MW) of new electricity generation capacity to meet growing demand, with around 700 MW to be awarded to projects based on liquefied natural gas (LNG). Energy and Mines Minister Victor Hugo Ventura said natural gas would be one of the drivers of economies of Central American countries. The tender is closing in November and is open for companies worldwide.
11 June: Developers plan to add 18.7 gigawatt (GW) of combined-cycle capacity to the US (United States) power grid by 2028, following minimal additions in the previous year, the Energy Information Administration (EIA) said. About 4.3 GW is already under construction, according to the EIA. Most of the country’s existing natural gas-fired capacity comes from combined-cycle gas turbines (CCGTs), which are flexible and efficient power generators. Additions of 1.6 GW of CCGT are planned for 2025, the EIA said, a sharp increase from the 98 MW added in 2024 at Louisiana’s Plaquemines plant. More than half of the 3.3 GW expected in 2026 is already under construction, while most of the additions planned for 2027 are not yet under construction. An additional 10.6 GW could be added in 2028, potentially marking the largest annual increase in CCGT capacity since 2018, the EIA said.
16 June: A US (United States) Senate panel proposed a full phase-out of solar and wind energy tax credits by 2028 but extended the incentive to 2036 for hydropower, nuclear and geothermal energy, which are favored by President Donald Trump’s administration, according to a draft bill circulated. The draft bill, part of a sprawling Republican budget package, made several changes that clean energy advocates pressed for to a bill passed in the House. In a change from the House bill, the Senate would grant 100 percent of the credit to hydropower, nuclear and geothermal facilities until 2033, then phase it out to zero by 2036, according to the draft.
13 June: Woodside Energy and the Australian government said they have extended the consultation period for conditions tied to the environmental approval of the firm's North West Shelf LNG project extension, following conditional clearance. The project, located in the Burrup peninsula in Western Australia, is the country’s oldest and largest LNG plant and a key supplier to Asian markets. Environmental groups have long opposed its extension on concerns that the emissions could affect the ancient Murujuga rock art in the area, which is culturally and spiritually significant to Indigenous Australians.
11 June: The World Bank’s board has agreed to end a longstanding ban on funding nuclear energy projects in developing countries as part of a broader push to meet rising electricity needs, the bank’s president Ajay Banga said. The global development bank, which lends at low rates to help countries build everything from flood barriers to railroads, decided in 2013 to stop funding nuclear power projects. It announced in 2017 it would stop funding upstream oil and gas projects beginning in 2019, although it would still consider gas projects in the poorest countries. The nuclear issue was agreed fairly easily by board members, but several countries, including Germany, France and Britain, did not fully support changing the bank’s approach to embrace upstream natural gas projects. The Trump administration has been pushing hard for ending the ban on nuclear energy projects since taking office. The US is the bank’s single largest shareholder - at 15.83 percent, followed by Japan with 7 percent and China with close to 6 percent - and the bank’s decision to broaden its approach to energy projects will likely please President Donald Trump, who withdrew the US from the Paris Climate Agreement and its emission-reduction targets as one of his first acts in January. Banga said the World Bank Group would work closely with the International Atomic Energy Agency to strengthen its ability to advise on nuclear non-proliferation safeguards, safety, security and regulatory frameworks. The bank would support efforts to extend the life of existing nuclear reactors, along with grid upgrades. It would also work to accelerate the potential of small modular reactors.
11 June: European Union (EU) countries may demand that Brussels simplify the EU’s methane emissions law, which has stoked concerns from companies that it could hamper imports of US (United States) liquefied natural gas (LNG). From this year, the EU requires importers of oil and gas to monitor and report the methane emissions associated with these imports. Methane, which escapes from leaky gas infrastructure, is the second-biggest cause of climate change after carbon dioxide emissions. The EU agreed its methane law last May, but the policy has come under increased scrutiny as the EU attempts to quit Russian gas - and to buy more US LNG to replace it. Washington and Brussels have each indicated that EU purchases of US LNG could form part of a broader US-EU trade deal. Romania and Slovakia are among countries warning that the methane law could disrupt gas imports. Some US LNG firms have warned they will struggle to comply with the EU law, since the fragmented nature of the country’s industry means they cannot track emissions along their entire value chains, down to specific gas wells.
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