Electricity Derivatives in India: How C&I Consumers Can Hedge Power Price Risk on the Power Exchanges
Hedging-Derivatives
Electricity Derivatives in India: How C&I Consumers Can Hedge Power Price Risk on the Power Exchanges
Electricity Derivatives in India: How C&I Consumers Can Hedge Power Price Risk on the Power Exchanges
If a plant buys power on the exchanges, its electricity cost is no longer a tariff. It is a market price. It moves with hydro inflows, coal stocks, heat waves and evening peak scarcity, and it moves fast enough to wreck a quarterly cost budget that was signed off in April. Since July 2025, Indian C&I consumers have had a genuine financial tool to lock that price in advance. Most have not used it yet.
How can industrial companies hedge against electricity price volatility in India?
There are three practical routes, and serious buyers use a combination of all three.
Physical hedges on the power exchanges. Term Ahead Market and Long Duration Contracts on power exchanges like IEX, PXIL and HPX let a buyer purchase fixed price, fixed quantity blocks for weeks or months ahead instead of taking whatever the day ahead market clears at.
Financial hedges through electricity futures. Cash settled monthly futures now trade on MCX and on the NSE, regulated by SEBI as commodity derivatives. A buyer fixes a price without touching the physical supply chain.
Bilateral fixed price structures. A fixed tariff third party open access PPA, a group captive arrangement or a virtual PPA that works as a contract for differences.
The honest summary is this. The physical route is mature, the bilateral route is well understood, and the financial route is roughly a year old and still thin. The sensible approach is to hedge the volatile slice of load with futures. A buyer should not put the entire power book into an instrument whose order depth has not been checked on screen.
Why this matters more than it did three years ago
A growing share of C&I load in India sits outside a regulated tariff. Open access consumers, captive users selling surplus and anyone topping up through the day ahead or real time market now carry direct exposure to spot price formation. That exposure is asymmetric. Discom tariffs move once a year through a tariff order. Exchange prices can double inside a fortnight in a hot May and collapse in a wet August.
For a CFO, the problem is not the average price. It is the variance. A ₹1.00/kWh swing on 30 million units a year is ₹3 crore of unplanned cost, and it lands in the quarter the business least wants it.
Key terms, defined properly
Electricity future
A standardised, exchange traded contract to settle the difference between a price fixed today and a reference electricity price published later. Indian electricity futures are cash settled, so no power is delivered. MCX contracts are monthly, quoted in rupees per MWh, with a trading unit of 50 MWh, and listed for the current month plus the next three months. Settlement is referenced to the volume weighted average of the day ahead market Unconstrained Market Clearing Prices on IEX across the calendar days of the expiry month (MCX contract specification, Electricity Futures Monthly Base Load). The NSE contract carries the same symbol family, ELECMBL, and a comparable design, with its settlement rate drawn from the reference prices of the DAM, GDAM and RTM markets (NSE Electricity Futures contract specifications). A buyer should read the live contract specification before sizing a trade, since lot size and the reference price definition drive the hedge ratio.
Forward or physical term contract
A contract that ends in actual delivery of electricity. On Indian power exchanges these appear as Term Ahead Market contracts and Long Duration Contracts. These sit under CERC's jurisdiction because they involve physical delivery, and are treated as Non Transferable Specific Delivery (NTSD) contracts under the Securities Contracts (Regulation) Act 1956.
An NTSD contract must be settled only by actual physical delivery of the goods, with no financial netting off, and the rights and liabilities of the original buyer and seller cannot be transferred to a third party. Section 30A of the SCRA exempts compliant NTSD contracts from certain provisions of the Act, which protects genuine commercial delivery transactions from being treated as illegal or speculative options. This is why physical power forwards on the exchanges sit with the sectoral regulator, CERC, while cash settled financial derivatives sit with SEBI.
Option
The right, not the obligation, to buy (Call) or sell (Put) at a fixed price. Useful for capping peak season exposure while keeping the upside if prices fall. India's electricity options market is not yet meaningfully liquid.
Contract for differences and virtual PPA
A purely financial swap of a fixed price against a floating market price, with no physical wheeling. A VPPA achieves this while also delivering environment attributes such as I-RECs. This is the structure most global corporates recognise, and it is increasingly used in India by consumers whose loads are spread across states.
Basis risk
The gap between the price a hedge settles against and the price the buyer actually pays. This is the single most misunderstood item on the list. More below.
Who regulates what: SEBI or CERC
The split that both regulators now work to is simple. If the contract results in physical delivery of electricity, it is a power market product and CERC governs it under the Electricity Act 2003. If it is settled in cash with no delivery, it is a securities market product and SEBI governs it under the Securities Contracts (Regulation) Act. That is why Term Ahead Market purchases are executed by a power trader on the exchange while electricity futures are executed by a SEBI registered commodity broker in a demat linked trading account.
The practical consequence for an organisation is administrative, not academic. Two counterparties, two sets of documentation, two approval trails and two different internal owners. Most companies discover this after the board has already approved the hedge in principle.
How a cash settled hedge actually works
Take an illustrative case. A textile unit buys 4,000 MWh a month through open access from the day ahead market. Budget rate approved for the year is ₹4.80/kWh landed. The energy component of that budget is roughly ₹4,300/MWh, with the rest being open access charges and losses.
In February, the plant buys 80 lots of the May futures at ₹4,300/MWh, matching its expected May volume of 4,000 MWh at a lot size of 50 MWh.
If May day ahead prices average ₹5,600/MWh, the physical bill is about ₹52 lakh above budget on the energy component. The futures position gains about ₹1,300/MWh across 4,000 MWh, roughly ₹52 lakh. Net effect close to neutral.
If May averages ₹3,900/MWh, the physical bill is about ₹16 lakh below budget and the futures position loses a similar amount. Again close to neutral.
That is the whole point. A hedge is not a bet on direction. It converts a variable cost into a known cost, and it lets a business quote customer prices with confidence.
The four risks that get skipped in the pitch
Basis risk is the real exposure
The futures settle against an exchange reference price. The invoice includes transmission charges, wheeling charges, cross subsidy surcharge, additional surcharge, state losses and deviation settlement charges. None of that is hedged. If a state raises the additional surcharge, no futures position protects against it. The energy component should be hedged and the rest managed through regulatory strategy, not through derivatives.
Volume risk cuts both ways
Hedge 4,000 MWh and then run at 60% utilisation because of a demand slump, and the buyer is left holding a financial position against consumption that never happened. That is speculation by accident. Only firm, must run baseload should be hedged. Swing volume should be left unhedged.
Margin is a cash flow item
Exchange traded positions require initial margin and daily mark to market settlement. The MCX contract carries an initial margin of a minimum 10% or SPAN, whichever is higher (MCX contract specification). A hedge that is working perfectly on an economic basis can still demand cash on a Tuesday. Treasury needs to know this before the first trade, not after the first margin call.
Accounting and governance
Without formal hedge designation under Ind AS 109, mark to market moves hit profit and loss even when the underlying physical exposure has not been recognised yet. An auditor will ask for documented hedge relationships and effectiveness testing. The hedge policy, board delegation and hedge documentation should be drafted before the position is opened. Retrospective designation is not available.
Market coupling changes the reference price being hedged
CERC has directed the implementation of market coupling for the day ahead segment, with a single clearing price computed across power exchanges and Grid-India as the coupling operator. Details and timelines are on the CERC site.
For hedgers this is good news. A single day ahead clearing price removes the cross exchange price gap that made settlement references debatable, and it deepens the pool of volume behind the reference price. A cleaner reference price supports better liquidity in futures, because market makers can quote with less uncertainty about what they are settling against.
One caution. Any change in how the reference price is computed changes the behaviour of the hedge. The settlement clause in the contract specification should be read again each time the market design changes.
How discoms can use hedging and what SERCs should require
Discoms are the largest single buyers on the power exchanges, and they carry the same spot price exposure as any C&I open access consumer, only larger. When a discom buys short term power on the day ahead or real time market to cover a demand gap, an unhedged spike flows straight through to the power purchase cost and then to consumers through fuel and power purchase adjustment charges. The consumer pays for the volatility twice, first in the bill and then in the uncertainty.
Electricity futures give discoms budget certainty on short term procurement. A discom that knows it will buy a recurring block from the market each summer can lock that energy cost months ahead, the same way a manufacturer does. The instrument was designed with this use in mind, listing discoms alongside generators and industrial users as intended participants (NSE Monthly Electricity Futures brochure).
State Electricity Regulatory Commissions have a role here that goes beyond permission. An SERC approves a discom's power procurement plan and its cost pass through. It is well placed to require that a discom's exposure to volatile spot purchases is appropriately hedged, with clear volume limits, tenor limits and a no speculation boundary, so that market exposure taken on the consumer's behalf is managed and not left open. A hedging mandate framed inside the procurement approval protects the consumer from the peak season shock that no annual tariff order can absorb. As Prabhajit Sarkar, Founder and CEO of Ampera Energy, puts it, "We need to dwell more on how discoms can participate and the role of SERCs in enabling that."
Which hedge suits which consumer
Steady baseload, single state, high open access volume. Physical term contracts for the base, futures for the seasonal peak months of April to June and September to October.
Multi state manufacturing footprint. Financial hedges and virtual PPAs travel better than physical open access, which resets with every state's regulations.
Captive or group captive generator with surplus. The buyer here is a seller. Futures let a generator lock a floor on merchant sales without committing to a long term bilateral tie up.
Energy intensive process with pass through customer contracts. Hedge only the unrecovered portion. Double hedging a cost already passed through creates the exposure the hedge was meant to remove.
Load under 5 MW with mostly discom supply. Derivatives are not the priority. Contract demand optimisation, power factor and rooftop solar will give more rupees per hour of management attention.
Do this week
Pull twelve months of unit level data and split the energy cost into fixed regulated charges and market linked energy cost. Only the second bucket can be hedged. Most companies over estimate it.
Calculate the rupee impact of a ₹1.00/kWh adverse move on that bucket. If it is material to EBITDA, this becomes a treasury item and not just an operations item.
Get a one page hedging policy drafted with volume limits, tenor limits, approval authority and a clear no speculation clause. Take it to the board or risk committee this quarter.
Open a screen and look at actual bid ask depth on the next three monthly electricity futures contracts before building any plan around them.
Decide the split. The default recommendation for a first year programme is to hedge 50 to 70% of firm baseload energy for the next two quarters and nothing beyond that until the buyer has lived through one settlement cycle.
Ampera Energy structures physical and financial hedges together, so the basis between what is hedged and what is actually paid stays visible. To have exposure quantified before the next peak season, send twelve months of energy bills and open access schedules and we will size the hedge for you.
FAQ
Are electricity derivatives legal in India?
Yes. Cash settled electricity futures are regulated commodity derivatives under SEBI and trade on MCX and NSE. Physically delivered contracts on power exchanges are regulated by CERC under the Electricity Act 2003 and are treated as Non Transferable Specific Delivery contracts under the SCRA.
Does a company need to be a power trader or a licensee to trade electricity futures?
No. Financial electricity futures are accessed through a SEBI registered broker, like any other commodity derivative. Physical exchange purchases still need to go through a registered trading member of the power exchange.
Does a futures hedge reduce open access charges?
No. Futures hedge the energy price only. Transmission charges, wheeling charges, cross subsidy surcharge, additional surcharge and deviation settlement charges are unaffected. Those need regulatory and structural strategy.
What is the difference between a virtual PPA and an electricity future?
A VPPA is a bilateral, long tenor contract for differences usually tied to a specific renewable project, and it typically delivers environment attributes. An electricity future is a short tenor, standardised exchange contract with a clearing house as counterparty and no attributes attached.
How much of the load should a company hedge?
Hedge firm baseload consumption that is confident to materialise, and only the market linked portion of its cost. Start at 50 to 70% of that volume for two quarters ahead. Leave swing volume and uncertain expansion load unhedged.
Will hedging save money?
Not necessarily, and that is not the objective. Hedging reduces variance. Over several years a hedged buyer pays close to the market average with far more predictability, which is what lets a business price contracts and protect margins.
What is the biggest mistake first time hedgers make in India?
Hedging a volume they do not consume, or hedging against a reference price that does not match their actual delivered cost. Both convert a risk management tool into a new risk.
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