MNRE's 500 MW CfD scheme represents India's most ambitious step toward market-based renewable integration. This analysis examines the mechanics, trade-offs, and what it means for every stakeholder in the chain.

Setting the Scene

India crossed 215 GW of installed renewable capacity (excluding Hydro) by February 2026 — a milestone achieved almost entirely on the back of long-term Power Purchase Agreements. That model served its purpose: it brought private capital into an uncertain sector, gave lenders the comfort of a DISCOM off-taker, and delivered dramatic cost reductions across solar and wind.

As India's power markets mature — with Green Day Ahead and Real Time Markets deepening, storage costs falling, and the system needing flexible, dispatchable RE at scale — a more sophisticated mechanism was inevitable. That mechanism, approved by the Ministry of New and Renewable Energy on 30 March 2026, is a Contract for Difference (CfD).

The 500 MW pilot, to be implemented by Solar Energy Corporation of India (SECI) as nodal agency, is modest in scale but momentous in intent. It is the first time India has formally tested a market-settled, exchange-integrated revenue stabilisation instrument for renewable energy.

"The PPA gave India its renewable foundation. The CfD is the architecture India needs for the next chapter — competitive, liquid, and market-honest."

How the Mechanism Works

The core logic is elegant: RE generators sell power directly on exchanges, competing at market prices. SECI then settles the difference between the competitively discovered strike price and the zonal Day-Ahead Market (DAM) reference price — paying generators when the market falls short, collecting from them when the market pays more. Th

If MCP < strike price: SECI pays the shortfall to the generator from the CfD pool.

If MCP > strike price: the surplus flows into the CfD pool.

Profit/loss sharing: 30% to the generator, 70% to the pool, reconciled monthly. SECI retains up to 25% of pool profits as its operational income, subject to a 2-year withdrawal moratorium. e settlement formula, simplif

The bidding sequence for generators is carefully prescribed: Green Day Ahead Market (GDAM) first, then Order Carry Forward (OCF) to the DAM, and any cleared or curtailed volume must then be bid in the Real Time Market (RTM). This staging minimizes curtailment risk and ensures orderly market participation.

Project structure: Build-Own-Operate basis for 12 years. Maximum bid capacity per bidder is capped at 125 MW (375 MWh in energy terms), encouraging broad participation. Generators must supply 1,500 MWh of RE power during any three hours of non-solar hours daily — making BESS-backed or hybrid projects the natural fit.

A notable innovation: Renewable Energy Certificates (RECs) generated from volumes sold in brown markets must be sold by the developer, with proceeds deposited into the CfD pool — recycling a green attribute instrument directly into the settlement fund.

India vs. the UK — Two Generations of CfD Design

The UK’s Contract for Difference, operated by the Low Carbon Contracts Company (LCCC) since 2014, is the world’s most mature and studied version of this instrument. Comparing the two reveals how India’s pilot is directionally aligned but structurally provisional.

The most significant structural departure is the 30:70 profit split. The UK’s true two-way CfD means the government (via LCCC) fully participates in downside and upside. India’s design is closer to a hybrid floor guarantee — generous to developers in the downside but taxing a large share of their upside.

"India’s pilot is directionally aligned with the UK model but structurally provisional — thinner in financial backstop, less precise in benchmark construction, and more reliant on SECI’s institutional capacity than on a legislated industry levy."

Conclusion

The proposed CfD does not replace the economic role of PPAs; it redefines it. While PPAs remain superior for ensuring bankability, long-term revenue certainty, and risk insulation, the CfD introduces a market-linked framework that prioritizes flexibility, price discovery, and fiscal discipline.

Its core value lies at the system level—deepening power markets, enabling time-of-day pricing signals, and reducing long-term liabilities on DISCOMs and government. However, at the project level, the CfD offers only a partial hedge, with reduced tenure, shared upside, and continued exposure to market and volume risks. The 30:70 profit-sharing structure further weakens incentives by capping gains while only partially mitigating downside, creating a controlled rather than fully market-aligned participation model.

In effect, the CfD shifts the sector from a “contract-driven” regime to a “market-integrated” one. The winners will be entities capable of managing price risk, forecasting accurately, and optimizing dispatch—particularly those with storage or trading capabilities. Government and system operators benefit from greater flexibility and fiscal control, while traditional, risk-averse developers and lenders may find the model less attractive.

Overall, the CfD should be seen not as a superior alternative to PPAs, but as a transitional instrument—useful for evolving the market, but not yet a complete substitute for the stability that PPAs provide.