India
The world's third-largest electricity market, cleared on a single national grid at one frequency — but with only a thin, volatile exchange slice sitting on top of a vast base of long-term PPAs.
Overview
India is the world's third-largest electricity market and almost none of it is priced on an exchange. What trades is a thin, volatile slice sitting on a vast base of long-term power purchase agreements. Get that structure clear before you take a position, because everything else follows from it.
Installed generating capacity passed 500 GW in September 2025, more than half of it non-fossil by nameplate rating (Ministry of Power, via Deccan Herald). Nameplate is not output. Coal still produces around two thirds of the electricity actually generated, because solar and wind run at capacity factors a thermal unit would be shut down for.
Wholesale power trades on three exchanges: the dominant Indian Energy Exchange (IEX), with PXIL and HPX behind it, across day-ahead, real-time, term-ahead and green segments. Gas trades separately on the Indian Gas Exchange (IGX). Short-term transactions of every kind came to about 238 billion units in 2024-25, of which the exchanges carried 108.62 BU (Power Line). The rest moves under contracts signed years in advance.
State-owned distribution companies are the buyers on those contracts, and their finances are the weak point in the whole sector. Aggregate technical and commercial losses ran at 15.04% in 2024-25, with the cost-recovery gap narrowed to ₹0.06 per unit (14th Integrated Rating report, via PSU Watch). A discom that cannot pay reliably under-contracts, buys short, and then pays whatever is asked when demand spikes. That behaviour is most of the volatility in the exchange slice.
In most liberalised markets the exchange price is the market. In India it is the residual, whatever is left once the long-term PPAs have dispatched. Residual markets are thin, and thin markets move.
Market structure
One national grid at one frequency. Three competing exchanges. And underneath them a contracting base of bilateral PPAs that never touch a market screen.
Who does what
| Function | Body | Role |
|---|---|---|
| Power exchanges | IEX, PXIL, HPX | Day-ahead, real-time, term-ahead and green contracts |
| Gas exchange | IGX | Physical delivery-based gas contracts, intraday to semi-annual |
| System operation | Grid-India | National and regional load despatch; scheduling and despatch |
| Economic regulation | CERC | Inter-state tariffs, market design, exchange oversight |
| State-level regulation | State ERCs | Retail tariffs and discom performance |
| Technical planning | CEA | Capacity, resource adequacy and generation statistics |
| Gas regulation | PNGRB | Pipelines, city gas networks and the gas exchange regime |
The exchange is a slice, not the market
Most Indian generation sells under 25-year PPAs between a generator and a state discom, on a two-part tariff: a fixed capacity charge that pays for the asset whether it runs or not, and a variable energy charge for fuel. Those megawatt-hours dispatch against a contract, not against a price. The exchange picks up the leftovers, whether that is a discom short of its contracted position, a generator with unrequisitioned capacity or an industrial buyer on open access.
So exchange prices do not tell you what the system costs. They tell you where it is under strain. Tighten the residual and the day-ahead price can hit the regulatory ceiling inside a single 15-minute block. Flood the middle of the day with solar and it falls towards the floor. On 15 August 2026 the unconstrained day-ahead clearing price ran from ₹300 to ₹9,913 per MWh across the day (IEX market snapshot).
Three exchanges, converging on one price
IEX carries close to 90% of exchange volume, with PXIL and HPX sharing the rest (Business Today). Each exchange used to discover its own price. From January 2026 CERC has been phasing in market coupling for the day-ahead market: bids from all three platforms are pooled into one clearing price, with the exchanges taking turns as coupling operator and Grid-India sitting behind them as backup and auditor. Cross-exchange basis goes away. The day-ahead price becomes a genuinely national number.
Infrastructure — power and gas
One synchronous grid covers the whole mainland at 50 Hz, which is unusual for a system this size. The gas network has not caught up: it is still regional rather than national.
Power
One frequency
The five regional grids are synchronously interconnected into a single national system at 50 Hz. Energy can in principle run from Gujarat to Assam without touching a converter station.
Transmission corridors
Interregional capacity is large, but not unlimited. When the coupled solution has to be re-run against network limits, congestion surfaces as area-specific clearing prices.
Coal at the core
Thermal plant sits near the eastern coalfields. Solar and wind sit in the west and south. The grid's job is increasingly to carry renewable energy away from where it was made.
A national clearing price only means anything because of that single-frequency design. Japan, split at 50 and 60 Hz, watches its two halves price apart routinely. When Indian regions diverge it is a transmission constraint rather than a physical incompatibility, and constraints can be built away given money and time.
Gas and LNG
India produces a fair amount of its own gas. Not enough, so the balance comes in as LNG. Output from legacy domestic fields sells at an administered price and everything else at a market price. IGX now settles at 19 delivery points across LNG terminals, domestic field landfalls and pipeline interconnections (IGX, July 2026). That count is a decent proxy for how far physical liquidity now reaches.
Schematic — system topology, not a geographic map. The long-term PPA base carries the bulk of the energy; the short-term layer, of which the exchanges are one part, sits on top of it; system operation sits under everything. Widths are illustrative of layering, not scaled to volume.
Demand and supply
Demand is growing fast and solar faster. When the sun goes down, coal still answers the phone.
Demand
Few large markets have demand growth this structural. Air conditioning, industrial load and electrification all pull the same way. Consumption hit 170.70 billion units in July 2026 alone, up around 11% year on year (Business Standard). That is the mirror image of Japan, and it changes what a position here is actually exposed to. Nobody is worried about stagnation. The question is whether supply keeps up.
Supply
Coal is the backbone. Solar has grown far enough to soften midday prices as a matter of routine, but the evening peak still lands on thermal plant, and there is very little storage and no real demand-response market to take the edge off. Average prices are not falling. The intraday spread is widening instead.
Shares for 2025, rounded. Source: Low Carbon Power, corroborated by Ember.
2024-25 short-term transactions totalled about 238 BU, roughly 15% of generation. Source: Power Line.
Gas makes a couple of per cent of Indian electricity, and sets the price in the western and southern states more often than that share suggests. Small fuels with large influence on the price are the ones that get mis-sized on a risk report.
Price setting mechanism
A uniform-price auction over 96 fifteen-minute blocks a day, clearing a residual volume under a capped price. The fuel costs that drive it are set outside the market altogether.
The power auction
Buyers and sellers bid for each 15-minute block, 96 of them a day. The exchange builds a supply stack and a demand stack and clears them against each other, and the intersection is one price paid by every buyer and received by every seller in that block. Under market coupling the stack is built from all three exchanges at once, giving a single national clearing price before network constraints go on. Where transmission binds, the clearing is re-run and area prices separate.
What separates this from a pool market is what is in the stack. Contracted PPA generation is already committed and never bids. What bids is surplus: an unrequisitioned thermal unit, merchant capacity, a discom long a block. The marginal unit is therefore often an expensive coal plant on part load, or an imported-coal unit. Day-ahead prices can sit well above the average cost of generation while the system as a whole is comfortably long.
The cap, and why it matters
A regulatory ceiling sits over exchange prices. Unconstrained clearing reached ₹9,913 per MWh on 15 August 2026 (IEX market snapshot), pressed hard against the ceiling in individual blocks while the daily average came in at ₹3,281 per MWh. Write a hedge here and your upside is truncated by regulation rather than by fundamentals. The tail risk on a short position is bounded, and so is the value of an out-of-the-money call.
Gas pricing is administered, not discovered
Domestic gas from legacy fields sells at the APM price, set at 10% of the monthly Indian crude basket, floored at $4 and capped at $7/MMBtu since 1 April 2026 (Ministry of Petroleum and Natural Gas, via ETV Bharat). Deepwater and difficult fields get a separate, higher ceiling. Imported LNG and free-market domestic gas price off the international market like everyone else. IGX's GIXI index settled at $19.17/MMBtu in July 2026 (IGX, July 2026).
Which bucket a buyer's molecules come from decides their economics. APM gas at $7 and free-market gas near $19 are not competing supplies. They are different entitlements. Model Indian gas demand without splitting the two and the answer is out by more than a factor of two.
Hedging
Cash-settled electricity derivatives launched in July 2025, the first route generators and discoms have had to lock forward prices (Power Line). Liquidity is thin so far. The exchange price is nonetheless becoming a settlement reference as well as a physical one.
Regulatory regime
Two tiers: federal for inter-state trade, state-level for retail, with the gas regulator off to one side entirely. Where a transaction sits decides who governs it.
| Body | Remit |
|---|---|
| Ministry of Power | Policy, schemes and the legislative framework |
| CERC | Inter-state tariffs and transmission, market design, exchange and coupling regulation |
| State Electricity Regulatory Commissions | Retail tariffs, open access charges, discom performance |
| Grid-India | National and regional load despatch, scheduling, deviation settlement |
| CEA | Technical standards, resource adequacy planning, generation statistics |
| PNGRB | Gas pipelines, city gas distribution and the gas exchange regime |
Why the federal split matters commercially
A generator selling across a state border deals with CERC. A consumer buying through open access deals with their State Commission, and with state-level charges that can be revised in ways that gut the economics of a contract already signed. Open access has been legally available for two decades. Whether it is usable depends on the state, and that variation, not the national rules, decides whether a corporate power purchase works.
Market coupling
Nothing recent matters more than the phased introduction of market coupling from January 2026, starting with day-ahead and extending to term-ahead through a shadow pilot. CERC has also been reviewing exchange transaction fees, currently charged close to the 2 paise per unit ceiling, with reductions on the table (Business Today). Coupling kills price differences between platforms. It also moves the exchanges' competitive ground from price discovery to services and fees.
Distribution reform is the binding constraint
Every serious analysis of the Indian power sector ends up in the same place. A market cannot be better than its buyers. AT&C losses of 15.04% in 2024-25, a year in which the sector posted its first collective profit in over a decade (14th Integrated Rating report, via PSU Watch), mean the counterparty on most long-term contracts has only just stopped losing money. Federal scheme after federal scheme has gone at this, and metering and collection have genuinely improved in the better states. Take multi-year Indian power exposure and you have taken a state-level credit view whether you priced one or not.
Key links
Primary sources for this market. Figures on this page are drawn from these and from published market data.