Virtual Power Purchase Agreements Under CERC Regulation 14A: What Industrial Consumers Need to Know
CERC Regulation 14A creates India’s first regulatory framework for Virtual PPAs — allowing industrial consumers to financially contract for renewable energy attributes without physical delivery, wheeling charges, or open access approval delays. It satisfies RCO compliance. It does not reduce CBAM embedded emissions. Understanding that distinction is the starting point for every VPPA decision.
Key Takeaways
- A Virtual Power Purchase Agreement (VPPA) is a financial contract between an industrial consumer and a renewable energy generator in which the consumer pays a fixed price (the strike price) for the renewable energy attribute — the REC — while electricity physically flows to the grid, not to the consumer’s facility. The financial settlement is the difference between the strike price and the market price of electricity — the consumer pays the generator the strike price, the generator sells the physical electricity at the market price, and the net financial flow between them is the difference. The consumer receives RECs that can be used for RCO compliance.
- CERC Regulation 14A, introduced in the March 2026 First Amendment, creates the legal framework for VPPAs in the Indian power market. Before this regulation, financial contracts for renewable energy attributes without physical delivery operated in a legal grey area in India — the regulatory framework for RECs existed, but the contract structure for a bilateral financial contract with settlement against market price had no explicit CERC recognition. Regulation 14A establishes VPPAs as a recognised instrument, defines the settlement mechanism, and allows VPPA-sourced RECs to be used for RCO compliance.
- The primary advantage of a VPPA over a physical open access PPA is geographic freedom. A physical open access PPA requires the renewable generator to be connected to the state grid serving the industrial consumer’s facility, and the consumer pays wheeling charges and CSS for using the distribution network. A VPPA has no geographic constraint — an aluminium smelter in Odisha can enter a VPPA with an offshore wind project under development in Tamil Nadu, a pumped hydro project in Himachal Pradesh, or a solar park in Rajasthan without any wheeling charge or state-specific open access approval. The consumer receives RECs from wherever the best-value generator is located.
- VPPAs satisfy RCO (Renewable Consumption Obligation) compliance. The VPPA-sourced RECs can be surrendered to BEE for RCO compliance in the same way as RECs purchased on IEX or PXIL. For industrial consumers that have significant RCO obligations and face high wheeling charges or CSS in their home state — Maharashtra or Tamil Nadu, for example — VPPAs may be a more cost-effective RCO compliance pathway than physical open access procurement in those states.
- VPPAs do not reduce CBAM embedded emissions. This is the most important limitation that industrial consumers considering VPPA as a CBAM strategy must understand. CBAM’s Scope 2 embedded emission calculation uses the actual emission factor of the electricity physically consumed at the facility — not the carbon attribute of electricity contracted financially. A Maharashtra aluminium smelter that enters a VPPA with a Rajasthan solar project receives RECs for RCO compliance but continues to consume coal-grid electricity at the MSEDCL coal GEF — and that coal GEF is what determines its CBAM Scope 2 embedded emissions. VPPAs are RCO compliance tools. They are not CBAM embedded emission reduction tools. Only physical renewable electricity consumption at the facility changes the CBAM position.
- VPPAs are financially structured instruments with significant market risk for the industrial consumer if the spot electricity price falls substantially below the strike price for sustained periods. Unlike physical PPAs where the consumer receives actual electricity at the contracted tariff, the VPPA consumer’s financial outcome depends on the difference between the strike price and the market clearing price. In a period of abundant renewable generation and low spot prices — which is the expected direction of India’s power market — the consumer’s VPPA net payment could exceed a physical PPA’s cost. Risk management around this price exposure requires careful contract design including price floor provisions and volume flexibility clauses.
India’s renewable energy procurement landscape before March 2026 had a structural gap. Physical open access PPAs — where a generator delivers electricity through the state distribution network to an industrial consumer’s plant — were legally well-established under the Electricity Act 2003 and Green Energy Open Access Rules 2022. Procurement on IEX and PXIL through REC purchases was well-established as the compliance-without-physical-delivery alternative. But the intermediate structure that is standard in many global markets — a financial contract for renewable energy attributes between generator and consumer, settled against a market reference price, without physical delivery — had no explicit regulatory framework in India. CERC Regulation 14A fills that gap.
The global precedent for VPPAs is the US corporate renewable energy market, where technology companies like Google, Microsoft, and Amazon have procured hundreds of gigawatts of renewable capacity through financial contracts that enabled large-scale renewable development without the requirement for physical delivery to data centres distributed across multiple states. The financial settlement mechanism — strike price minus market price, with the generator selling physical electricity to the spot market and receiving the strike-to-market-differential settlement from the corporate buyer — allowed both parties to achieve their objectives without the geographic and infrastructure constraints of physical delivery. Regulation 14A brings this structure to India’s industrial market.
How a VPPA works under Regulation 14A: the mechanics
Under CERC Regulation 14A, a VPPA is structured as a bilateral financial contract between a renewable energy generator (the seller) and an industrial consumer or any eligible buyer (the buyer). The contract specifies a strike price in Rs per MWh and a contracted volume in MWh per period (typically monthly or annual). The generator physically delivers its electricity to the state grid or power exchange and receives the market clearing price. Separately, the financial settlement between generator and buyer occurs:
When the market clearing price is below the strike price, the buyer pays the generator the difference per MWh of contracted volume — ensuring the generator receives the strike price it needs for project bankability. When the market clearing price exceeds the strike price, the generator pays the buyer the difference — sharing the upside of high market prices with the buyer. In periods where the two prices are equal, no settlement payment is made. The generator issues RECs for each MWh of contracted renewable generation into the buyer’s registry account, which the buyer can surrender for RCO compliance.
VPPA vs Physical Open Access PPA vs REC Purchase — Compliance and Carbon Comparison
| Feature | Physical Open Access PPA | VPPA (Reg 14A) | REC Purchase on IEX |
|---|---|---|---|
| Physical electricity delivery | Yes — to facility | No — to grid | No |
| Wheeling charges / CSS | Yes — state-determined | No — not applicable | No |
| Geographic constraint | Must be in deliverable state/grid | None — any generator in India | None |
| Open access approval needed | Yes — state SERC process | No | No |
| RCO compliance value | Yes — full credit | Yes — via RECs issued | Yes — via RECs purchased |
| CBAM Scope 2 embedded emission reduction | Yes — actual RE consumed | No — physical RE not delivered to facility | No |
| CCTS Scope 2 GEI reduction | Yes — actual GEF reduction | Partial — depends on BEE treatment of VPPA RECs in GEI calculation | Partial — REC use may be credited in RCO but not direct GEI |
| Price risk | Low — fixed PPA tariff | Higher — settlement vs market price | Medium — REC market price variation |
The Maharashtra aluminium smelter case: when VPPA makes commercial sense. A Maharashtra aluminium smelter that needs 500 MW of RCO compliance renewable procurement faces a physical open access PPA market where CSS and wheeling add Rs 3.50 to 4.50/unit to the solar tariff — making landed RE cost Rs 6.50 to 7.00/unit, barely below the MSEDCL industrial tariff. A VPPA with a Rajasthan solar park at a strike price of Rs 3.00/unit incurs no wheeling or CSS — the financial settlement against the market clearing price is the only variable cost. If the market clearing price averages Rs 2.50/unit, the smelter pays Rs 0.50/unit net (the strike-to-market differential) and receives RECs equivalent to Rs 1,000/MWh compliance value. Effective RE attribute cost: Rs 1.50/unit. This is substantially cheaper than either physical open access in Maharashtra or REC purchase on IEX. The VPPA is the right tool here — but only for RCO compliance, not for CBAM. For CBAM, the smelter must also procure physical RE through a separate channel.
Who VPPA is designed for — and who should still use physical PPAs. VPPAs make most sense for industrial consumers in high-CSS states (Maharashtra, Tamil Nadu) where physical open access economics are unfavourable, for consumers whose facilities have physical constraints on electricity procurement that prevent open access metering, and for consumers whose primary driver is RCO compliance rather than CBAM Scope 2 reduction. Physical open access PPAs remain the better choice for consumers in low-CSS states (Odisha, Rajasthan, Gujarat) where the landed cost is already competitive, and — critically — for any consumer with significant CBAM exposure (aluminium smelters, steel plants) where physical RE consumption at the facility is required to reduce the CBAM-relevant Scope 2 embedded emission intensity. The VPPA is an RCO tool. The physical PPA is both an RCO tool and a CBAM tool. The choice depends on what the consumer is trying to achieve.
Frequently Asked Questions
What is the difference between a VPPA and a financial REC contract?
A REC purchased on IEX or PXIL is a spot or forward transaction where the buyer pays the current market price for an already-issued certificate. A VPPA is a long-term bilateral financial contract between a buyer and a specific generator, settled against the spot market price, with RECs issued from that specific project delivered to the buyer. The key difference is that a VPPA is project-specific and long-term — it provides revenue certainty to the generator that supports project financing — while an IEX REC purchase is anonymous and can draw from any registered project’s surplus. VPPAs also give the buyer the ability to contract for RECs from specific technology types (offshore wind, pumped hydro) that carry premium value under the CERC multiplier system.
Can VPPA-sourced RECs be used to reduce CCTS Scope 2 GEI?
This is an area where BEE’s detailed CCTS measurement guidelines have not yet been fully specific. For GEI calculations, the CCTS uses a gate-to-gate Scope 2 measurement based on actual electricity consumed at the plant multiplied by the applicable Grid Emission Factor. If BEE treats VPPA-sourced RECs similarly to REC purchases for GEI purposes — as energy attribute certificates that reduce the effective emission factor of consumed electricity on a proportional basis — then VPPA would provide partial CCTS Scope 2 GEI benefit. If BEE requires physical renewable electricity delivery to the plant for Scope 2 GEI reduction (consistent with the physical delivery approach used in some GHG accounting standards), VPPA would provide no CCTS GEI benefit. Compliance officers should monitor BEE’s CCTS detailed measurement guidelines for the specific treatment of VPPA RECs in GEI calculations as these are finalised.
What is the financial risk in a VPPA for the industrial buyer?
The primary financial risk in a VPPA for the buyer is the basis risk — the difference between the contracted strike price and the actual spot market clearing price. If spot prices fall significantly below the strike price (which is a plausible scenario as India’s renewable capacity surpasses demand growth), the buyer makes net payments to the generator that represent a cost above what they would have paid for RECs on the spot market. This risk can be managed through price collar provisions (setting a floor and ceiling on the strike-to-market differential settlement), volume flexibility clauses (allowing partial early termination if market conditions change materially), and portfolio approach (contracting multiple VPPAs with different generators at different locations to diversify basis risk).
Sources
- CERC — CERC (Terms and Conditions for Renewable Energy Certificate Transactions) (First Amendment) Regulations, 2026 — Regulation 14A
- Ministry of Power — Green Energy Open Access Rules 2022 — physical open access framework
- Bureau of Energy Efficiency — CCTS Detailed Procedure — Scope 2 GEI measurement methodology
- IRENA — Corporate Renewable Power Purchase Agreements — global VPPA market analysis, 2025
Related Reclimatize.in Research
India’s REC Market: How RECs Are Traded and What the Price Signal Means Open Access RE Landed Cost: Why the State You’re In Determines the Rs 1.50–2.00/Unit Gap CBAM and Indian Aluminium: Scope 2 Electricity Exposure Electricity Market and Open Access — Regulatory Repository India’s Pumped Hydro Storage: CERC’s 3× REC Multiplier