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India’s Renewable Energy Certificate Market: Pricing, Compliance Use, the 2026 CERC Amendment and the Critical Limitation Every CCTS-Obligated Buyer Needs to Understand

India’s REC market has been trading since 2011, but it remains poorly understood by the industrial energy managers who rely on it most. RECs were trading at Rs 345 to Rs 349 per certificate in May 2025 — a level so far below the Rs 3.72/kWh RCO penalty cap that it signals either systematic non-enforcement or extraordinarily cheap compliance. CERC’s First Amendment to the REC Regulations, notified in late March 2026, introduces the most significant structural changes in four years: a VPPA framework, revised technology multipliers reaching 4.0x for offshore wind and 3.0x for pumped hydro and battery storage, RCO alignment, and expanded eligibility for self-consumption projects. But for CCTS-obligated industrial plants, there is one thing that RECs — regardless of their multiplier or price — fundamentally cannot do. They cannot reduce a plant’s Scope 2 GHG emission intensity. That distinction is operationally decisive.

By Reclimatize.in 30 March 2026 Power and Carbon Markets  ·  Carbon Markets  ·  CCTS

How RECs work — the basic mechanic

A Renewable Energy Certificate is the instrument that separates the environmental attribute of renewable electricity from its physical delivery. When a renewable energy generator — a solar plant in Rajasthan, a wind farm in Tamil Nadu, a small hydro plant in Himachal Pradesh — generates one MWh of electricity and feeds it into the grid, the physical electricity merges with all other electricity in the grid and flows to whoever draws power. But the attribute of that electricity being renewable can be separated, certificated, and sold independently.

This separation is what makes the REC mechanism possible. The generator receives the commercial value of its electricity from whoever buys the power (typically a DISCOM or bilateral buyer). It then receives RECs from NLDC for the renewable generation — at a rate determined by the multiplier for its technology. Those RECs can then be sold on IEX or PXIL to obligated entities (DISCOMs, open access consumers, captive power plant operators) who need them to meet their RCO obligations, or to voluntary buyers who want to make green energy claims.

The REC mechanism was designed to solve a geographic mismatch problem in RPO/RCO compliance: a steel plant in a coal-belt state with limited renewable resources cannot easily procure wind power from Rajasthan through a direct PPA, but it can purchase RECs from generators in any state to meet its RCO obligation. The REC thus serves as a national tradable compliance instrument — decoupling the location of renewable generation from the location of the obligated consumer.

The Central Agency (NLDC) maintains the national REC registry, tracks certificate issuance and retirement, and provides data transparency to CERC. Trading takes place on the last Wednesday of every month in a double-sided closed-bid auction with price-prorata allocation — meaning buyers and sellers submit sealed bids and offers simultaneously, with prices matching from the intersection and allocation adjusted proportionally if bids exceed offers at the clearing price. CERC has also permitted fortnightly trading sessions (twice monthly rather than once) since October 2023, increasing market liquidity.

REC prices — what they tell us about compliance culture

India’s REC market has a price history that reveals as much about enforcement culture as about supply and demand fundamentals. RECs traded at approximately Rs 345 to Rs 349 per certificate in May 2025 trading sessions on IEX, with trading volume reaching 1.743 million certificates — a 65% year-on-year increase. These volumes suggest growing compliance activity. The prices, however, tell a different story.

At Rs 345 to Rs 349 per REC — equivalent to Rs 0.345 to Rs 0.349 per kWh — REC prices are dramatically lower than the maximum RCO buyout penalty of Rs 3.72 per kWh shortfall. If the penalty were routinely enforced, obligated entities would bid RECs up to just below the buyout price before switching to the penalty route. The fact that RECs have consistently cleared at 9 to 10% of the buyout price throughout 2024 and 2025 suggests one of two things: either there is a large surplus of RECs relative to actual compliance demand, or many obligated entities are not being held to the penalty at all and therefore have no incentive to bid RECs above their marginal valuation.

Prayas Energy Group’s August 2025 analysis is direct on this point: even at prices below Rs 500/REC, obligated entities have not rushed to buy RECs, implying they face no serious compliance consequence. An estimated 37 million RECs remained in inventory as of mid-2025, with 62 million either redeemed or retained — indicating significant surplus supply from generators relative to compliance demand. The first real test of whether BEE’s enforcement of the new RCO framework changes this behaviour will come with the FY 2024-25 compliance reporting cycle due by March 31, 2026.

The March 2026 CERC Amendment — what changed

CERC notified the First Amendment to the REC (Terms and Conditions for Renewable Energy Certificates for Renewable Energy Generation) Regulations in late March 2026. This is the most significant structural update since the 2022 Regulations introduced the multiplier system. The amendment makes five substantive changes.

1. RCO and Designated Consumer alignment

The amendment formally incorporates “Designated Consumer” and “Renewable Consumption Obligation (RCO)” as defined terms under the REC Regulations, aligning with the Energy Conservation Act 2001 as amended. This removes the definitional ambiguity that existed between the Electricity Act RPO framework and the EC Act RCO framework — confirming that a single REC can satisfy both obligations for entities covered under both statutes. This clarity was needed: several states had been operating dual compliance frameworks, and obligated entities needed regulatory certainty that their REC purchases could discharge both RPO and RCO liabilities.

2. VPPA framework (Regulation 14A)

The amendment establishes a formal regulatory framework for Virtual Power Purchase Agreements, following CERC’s VPPA Guidelines notified on December 24, 2025. Under Regulation 14A, RECs generated from VPPA-linked projects are automatically transferred to the consumer or Designated Consumer party to the VPPA. These RECs can be used for RPO or RCO compliance and are extinguished by NLDC upon use. Critically, VPPA-linked RECs cannot be traded on power exchanges after transfer — they are locked to the specific buyer for compliance use only. Surplus RECs from VPPAs can be carried forward to future compliance years but cannot be resold.

The VPPA framework opens a significant new procurement pathway for CCTS-obligated industrial plants that want renewable attribute certification without the complexity of a physical open access PPA. A manufacturing company in an industrially dense state with limited grid infrastructure for open access can now enter a VPPA with a solar or wind generator, receive the associated RECs, and use them for RCO compliance — without ever arranging for physical power delivery. However, as discussed below, VPPA-linked RECs share the fundamental limitation of all RECs: they do not reduce CCTS Scope 2 GHG emission intensity.

3. Revised Certificate Multiplier framework

The most commercially impactful change is the overhaul of the certificate multiplier system, which determines how many RECs a generator earns per MWh of generation. The amendment creates three multiplier regimes: a transitional structure for projects commissioned between December 5, 2022 and March 24, 2026; a new principles-based structure for projects commissioned after March 24, 2026; and a reversion to 1 REC/MWh for all projects after 15 years from commissioning date.

For projects commissioned after March 2026, multipliers are determined by a scoring model: 40% weight on tariff range, 30% on technology maturity, 30% on capacity credit or peak demand support. The scoring formula codifies the rationale already visible in the multiplier table — technologies that are more expensive, less commercially mature, and more valuable to grid stability receive higher multipliers. Technologies not listed above may receive case-by-case multipliers applied by CERC using the same principles.

4. Expanded eligibility for self-consumption projects

The amendment clarifies that renewable energy projects set up for self-consumption — factory-owned solar plants that do not qualify as captive generating plants under the Electricity Act’s technical definition — are now eligible to receive RECs, provided their tariff is not set under Section 62 or 63 and their electricity is not sold to an obligated entity for RPO/RCO compliance purposes. This expansion allows commercial and industrial players with on-site solar installations to monetise the environmental attribute of their generation through RECs, even when the underlying electricity does not qualify for the captive status that would otherwise be required.

5. Three-month discipline for REC applications

The amendment introduces a mandatory timeline: distribution licensees and open access consumers must apply for REC issuance within three months of the State Commission’s certification of their excess renewable procurement. Applications submitted after this period will not receive certificates. This provision addresses the historical problem of entities sitting on unclaimed renewable procurement for extended periods before applying for RECs — a practice that reduced market transparency and created unpredictable certificate supply. While the three-month rule adds administrative discipline, it may disproportionately burden smaller consumers and state utilities that face procedural delays outside their direct control.

The critical CCTS limitation — why RECs are not enough for CCTS-obligated plants

This is the most commercially important distinction in India’s entire green energy compliance landscape, and it is systematically underappreciated by industrial energy managers, sustainability teams, and even some compliance consultants. RECs — in any form, at any multiplier, purchased through any mechanism including VPPAs — do not reduce a CCTS-obligated plant’s Scope 2 GHG emission intensity.

The comparison is stark and decisive for CCTS-obligated industrial plants. RECs are a legal compliance tool — they satisfy the letter of the RCO obligation. But they leave the plant’s CCTS compliance position entirely unchanged because Scope 2 GHG emission intensity is based on physical electricity consumption from fossil sources, not on certificate ownership. The grid electricity that the plant consumed is still grid electricity; the fact that a REC was purchased representing renewable generation somewhere in the country does not change the carbon content of the electron that ran the plant’s motor or furnace.

This distinction becomes commercially decisive when the CCTS compliance calculation is run. A plant that meets its entire RCO obligation through RECs has: satisfied its legal obligation under the Energy Conservation Act; paid Rs 345 to Rs 500 per MWh in REC costs; and made no progress whatsoever on its CCTS GHG emission intensity target. A plant that meets the same RCO obligation through actual green open access procurement has: satisfied its legal obligation; saved money on electricity (typically); reduced its CCTS Scope 2 intensity proportionally; potentially earned Carbon Credit Certificates if the reduction brings it below its CCTS target; and reduced its CBAM embedded emission footprint for EU-exported products. For CCTS-obligated plants, the choice between RECs and actual RE procurement is not a compliance question — it is a strategic question with direct financial consequences across three regulatory frameworks simultaneously.

I-RECs and the international market

Beyond India’s domestic REC market, international REC certificates — I-RECs — are available for Indian RE projects through the International Renewable Energy Certificate Standard. In India, I-RECs are issued by the International Carbon Exchange (ICX), a wholly owned subsidiary of IEX, operating under regulatory guidance from CERC. I-RECs are primarily used by multinational corporations making global green energy claims — under RE100, CDP disclosures, and similar voluntary frameworks — and by supply chain partners of European companies seeking to document low-carbon electricity consumption for corporate sustainability reporting or ESG due diligence.

I-RECs carry the same fundamental limitation as domestic RECs for CCTS Scope 2 purposes: they are a certificate of renewable generation, not physical consumption. But for the specific purpose of substantiating green electricity claims to international buyers, ESG rating agencies, or supply chain sustainability requirements, I-RECs provide a globally recognised and standardised instrument that domestic Indian RECs do not — because domestic RECs are only verifiable within India’s regulatory framework and are not internationally recognised by global RE accounting standards such as GHG Protocol Scope 2 Guidance (market-based approach) or RE100.

For Indian exporters to markets where Scope 2 market-based accounting is required — primarily the EU and North America — the question of whether to use domestic RECs, I-RECs, or actual physical renewable procurement depends on the specific claim being made and the standard being applied. Under EU CBAM, which requires verified actual emission data, neither domestic RECs nor I-RECs are substitutes for actual renewable electricity consumption documented through ACVA-verified MRV.

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