India’s Power Sector, Explained: Who Generates, Who Delivers, and Where the Growth Is Coming From

How is the India power sector structured?

Electricity in India moves through four distinct layers, and each is governed differently. Understanding which layer a company operates in explains almost everything about what it does, what it earns and what it is accountable for.

The sequence matters. Generation was opened to competition and de-licensed; the wires that carry the power and the utilities that sell it to consumers remain planned and licensed. That is why India has hundreds of generating companies and roughly seventy distribution utilities, not the other way round.

Who is responsible for power generation in India?

Ownership of generating capacity has shifted decisively. As on 31 March 2026, the private sector held 278.6 GW of India’s 532.7 GW of installed capacity — 52.3% — against 24.4% owned by state utilities and 23.3% by central undertakings (Ministry of Power). The private sector is now the largest owner of India’s generating fleet.

That majority is heavily concentrated in renewables. Working from the Central Electricity Authority’s sector-wise table, private developers hold close to 86% of India’s renewable capacity excluding large hydro, but roughly a third of its coal capacity and none of its nuclear. Coal, nuclear and large hydro remain overwhelmingly public assets; wind, solar, hybrid and battery storage are being built largely by private companies competing in auctions.

Scale still sits with the public sector at the level of individual companies. NTPC crossed 90 GW of group installed capacity in May 2026 and reports holding about 17% of national capacity while contributing around 24% of India’s electricity generation as on 31 March 2026 — a reminder that a share of capacity and a share of output are not the same thing.

Who delivers the electricity once it is generated?

Delivery is a public, planned system, and it is one of the sector’s clearest success stories. India has operated as a single synchronous national grid since 31 December 2013, when the Southern region was connected through the 765 kV Raichur–Sholapur line. The transmission network crossed 5 lakh circuit kilometres at 220 kV and above in January 2026, with 1,407 GVA of transformation capacity and 120.3 GW of inter-regional transfer capacity — a 71.6% increase in network length since April 2014.

Planning and coordination of the inter-state system sits with the Central Transmission Utility of India Limited — a wholly owned subsidiary of POWERGRID — which took over the role with effect from 1 April 2021; POWERGRID itself remains the largest owner-operator of the inter-state network as a deemed transmission licensee. Real-time operation sits with Grid Controller of India Limited, which runs the National Load Despatch Centre and five Regional Load Despatch Centres. Inter-state transmission projects are awarded through tariff-based competitive bidding: 84 projects have been awarded under that route, 41 of them to private transmission developers, with 74 commissioned by December 2025.

Distribution is where the system meets the customer, and the Ministry of Power describes it as “the most important link in the entire power sector value chain” and “the cash register for the entire sector”. Its performance has improved measurably. Aggregate technical and commercial losses fell to 15.04% in FY2024-25 from 21.9% in FY2020-21. Distribution utilities posted an aggregate profit after tax of ₹2,701 crore in FY2024-25 — their first in aggregate — and the gap between the average cost of supply and average revenue realised narrowed to ₹0.06 per unit. Legacy dues owed to generators under the Late Payment Surcharge Rules 2022 fell to ₹4,109 crore by 10 February 2026, from ₹1,39,947 crore in June 2022, paid down over 43 monthly instalments.

What is the India energy mix — and how fast is it shifting?

This is where most summaries of the sector go wrong, because capacity and generation tell different stories. Both are true at the same time.

The reason is capacity utilisation. A coal plant can run most hours of the year; solar generates for part of the day and wind is seasonal. So non-fossil sources make up more than half of what India has built, and roughly three-tenths of what India actually produced last year. Both figures are moving in the same direction, and quickly: non-fossil capacity crossed 300 GW on 31 July 2026 — 300.50 GW, more than 54% of installed capacity and just over 60% of the way to the stated goal of 500 GW by 2030 — while the non-fossil share of generation rose from about 25% in FY2024-25 to about 29% in FY2025-26.

The generation numbers behind that shift are clear-cut. India generated 1,847.94 BU in FY2025-26. Renewable generation excluding large hydro rose 21.8% to 310.59 BU — solar up 21.2% to 174.76 BU, wind up 28.0% to 106.70 BU — while thermal generation fell 4.1%. Coal and lignite still supplied roughly 69% of India’s electricity, down from about 73% a year earlier. India added a record 55.29 GW of non-fossil capacity in FY2025-26.

Where is India’s electricity demand growth coming from?

Honestly answered: from the long run, not from every individual year. FY2025-26 was a soft year. Energy requirement was 17,07,493 MU against 16,95,188 MU the year before, and peak demand met actually fell, from 249.9 GW in FY2024-25 to 245.4 GW. Analysts attributed the flat year to a mild summer and an early monsoon, which cut cooling load through the months that normally set the peak.

The rebound was immediate. Electricity consumption grew 8.9% in April 2026, and the Ministry of Power told Parliament in August 2026 that peak demand rose about 12% year on year over April to June 2026. On 25 April 2026 at 15:38 hrs, India met a then-record peak demand of 256.1 GW — beating the previous record of 250 GW set on 30 May 2024 — with no shortage, while continuing to export to neighbouring countries; solar supplied 21.5% of the generation serving that peak. The record was surpassed within weeks, at 270.8 GW on 21 May 2026.

The structural case for growth is stronger than any single year. India’s per-capita electricity consumption was 1,460 kWh in 2024-25, up 52.6% from 957 kWh in 2013-14 — a rise of more than half in a decade, and still a fraction of consumption in industrialised economies. Rising incomes, industrial output, cooling demand and data-centre load all push in the same direction. That is the demand story, and it does not turn on one mild summer.

CEA now projects peak demand of 289 GW in 2026-27, 345 GW in 2029-30, 388 GW in 2031-32 and 459 GW by 2035-36, with energy requirement rising from 1,929 BU to 3,365 BU over the same period — a compound annual growth rate of 5.58% for peak demand and 6.41% for energy, measured from 2024-25. Meeting that while the mix changes is the whole of the sector’s agenda.

What does the energy transition in India require next?

Three build-outs are running in parallel, and the first two are led by government and the utilities.

• Transmission. The National Electricity Plan for transmission, launched in October 2024, sets out 1,91,000 ckm of new lines and 1,270 GVA of transformation capacity over the decade to 2031-32, including 33 GW of HVDC links, and identifies an investment opportunity of about ₹9.15 lakh crore. Inter-regional transfer capacity is planned to rise from around 120 GW to 143 GW by 2027 and 168 GW by 2032. The Ministry of Power reported roughly ₹5 lakh crore of transmission projects under bidding and execution as of April 2026.
• Storage. Storage converts variable generation into dependable supply. India had 2.93 GW / 8.66 GWh of battery storage commissioned as on 30 June 2026, with a large pipeline behind it. The National Electricity Plan targets 47.24 GW / 236 GWh of battery storage and 26.69 GW / 175 GWh of pumped storage by 2031-32.
• Firm capacity and fuel security. Coal remains part of the plan: the Ministry of Power has told Parliament that coal-based capacity is expected to reach about 315 GW by 2035-36, while no new gas-based or imported-coal-based plants are planned. Domestic supply is doing more of the work — imported coal blended for the power sector fell to 5.5 MT in the nine months to December 2025, from 12 MT a year earlier.

Read together, that is what navigating energy security while accelerating the low-carbon transition looks like in practice: firm capacity retained, the grid expanded and modernised by the utilities and regulators responsible for it, and variable renewable generation added around both. It is a division of labour. Generators build capacity to fit the network and the market design that government and utilities define; the system operator balances it in real time; and distribution utilities carry it to consumers.

What does this structure mean for a business buying electricity?

Two features of the system matter directly to a commercial or industrial buyer. The first is that most electricity is still sold under long-term contract: of 1,707 BU of electricity transacted in FY2025-26 — a market measure, distinct from gross generation — the short-term market accounted for 302.08 BU, or 17.7%, with power exchanges at 9.87%. That is why a multi-year power purchase agreement, not a spot purchase, is the standard instrument for locking in the cost of clean energy.

The second is that the price of grid supply moves on its own schedule. Tariffs are re-determined annually by state regulatory commissions. Time-of-day tariffs were mandated for commercial and industrial consumers with maximum demand of 10 kW and above from 1 April 2024, with peak-hour rates set at not less than 1.20 times the normal tariff and solar-hour rates at least 20% below it — though draft amendment rules issued in March 2026 propose extending that deadline to 1 April 2027 for large commercial and industrial consumers. Our earlier analysis of India’s electricity prices looks at those movements in detail. For buyers, the structural point is simple: a contracted supply arrangement converts a variable, annually reset cost into a predictable one, which is what renewable energy solutions for enterprises are designed to deliver.

Where do independent power producers fit in this structure?

An independent power producer is a privately owned generating company that builds, owns and operates power plants and sells the electricity to others. Given that private companies own 52.3% of India’s generating capacity and close to 86% of its renewable capacity, IPPs are not a niche within the sector — they are how most new generation now gets built.

Resolven is one of them: an EQT-backed renewable energy platform in India with a published portfolio of approximately 1.0 GW operational, 2.0 GW under construction and contracted and 2.3 GW under development, more than 20% of it in wind and battery storage. Its utility-scale solar, wind, hybrid and storage projects span eight states and supply central and state offtakers alongside corporate and industrial customers. That is the IPP role in one line: build generation and storage that fit the grid the utilities are building, and contract it to buyers who need the output to be dependable.

Frequently asked questions

Who owns most of India’s power generation capacity?

The private sector. As on 31 March 2026, private companies owned 278.6 GW of India’s 532.7 GW of installed generation capacity — 52.3% — against 24.4% held by state utilities and 23.3% by central undertakings, according to the Ministry of Power. Transmission, system operation and distribution remain predominantly public.

Is India’s electricity majority non-fossil?

By capacity, yes; by generation, not yet. Non-fossil sources were 53.2% of installed capacity as on 31 March 2026 and crossed 300 GW on 31 July 2026, but produced about 29% of the electricity generated in FY2025-26. Coal and lignite supplied roughly 69%. The difference is capacity utilisation: thermal plants run far more hours per year than solar or wind.

How fast is India’s electricity demand growing?

Over the long run, quickly; year to year, unevenly. FY2025-26 was flat — energy requirement rose to 17,07,493 MU and peak demand met fell slightly, on a mild summer and early monsoon. Demand then grew 8.9% in April 2026, and a new peak of 270.8 GW was met on 21 May 2026. CEA projects peak demand rising to 289 GW in 2026-27 and 388 GW by 2031-32, a compound annual growth rate of 5.58% measured from 2024-25.

Who operates India’s national grid?

Grid Controller of India Limited, through the National Load Despatch Centre and five Regional Load Despatch Centres, with State Load Despatch Centres operating at state level. India has run as one synchronous national grid since 31 December 2013. Inter-state transmission planning sits with the Central Transmission Utility of India Limited.

India’s power sector is no longer a single-story system. It is a public grid carrying a majority-private generating fleet to a demand base that is still early in its growth. Almost everything the sector does over the next decade follows from those three facts.