The grid’s carbon intensity determines every industrial Scope 2 footprint.
Coal generation fell 3% in 2025 — the first structural decline since 1973. RE generation rose 22% to 270 BU. Non-fossil installed capacity has crossed 52.57%, five years ahead of the 2030 target. But the Grid Emission Factor (0.710 tCO₂/MWh, CEA V21.0) still makes every industrial Scope 2 calculation material. We track RECs, CCC trading, CERC regulations, and the RE transition continuously.
The carbon intensity of India’s electricity grid determines the Scope 2 emissions of every industrial consumer in the country. The power sector is not just one sector among six — it is the foundation that every other sector’s decarbonisation sits on. A steel plant’s EAF electricity, an aluminium smelter’s pot-line power, a cement plant’s clinker grinding, a fertiliser plant’s utility steam, a freight corridor’s traction electricity — all of it passes through a grid whose emission factor is tracked by the CEA, published quarterly, and used in CCTS Scope 2 GEI calculations by every obligated entity. At 0.710 tCO₂/MWh (CEA V21.0), India’s grid emission factor is falling — but the rate of its decline determines how quickly the rest of the industrial economy can decarbonise by switching to electricity.
India has already exceeded 52.57 percent non-fossil installed capacity — crossing its earlier 2030 NDC target five years ahead of schedule. Coal generation fell 3 percent in 2025, the first structural decline since 1973. RE generation rose 22 percent to 270 billion units. With the Hormuz and Red Sea geopolitical supply shocks driving up imported fuel costs, the shift to domestic renewables is no longer just a carbon mandate—it is an energy security imperative. These are not incremental improvements; they are structural inflections that change the economic case for electrification across every sector simultaneously.
At the same time, India has built a domestic carbon market from scratch. The Carbon Credit Trading Scheme, with 740 obligated entities across nine sectors, officially launched trading in July 2026. The price at which Carbon Credit Certificates trade on regulated power exchanges is now the single most consequential number in the industrial decarbonisation economy.
The power sector and carbon market are interconnected and both are changing rapidly. These are the dynamics that matter most for industrial stakeholders.
Industrial tariffs, open access and renewable procurement
The Green Energy Open Access Rules 2022 and the ISTS waiver have materially improved industrial consumers’ ability to procure renewable electricity directly from generators. The economics of open access procurement vary significantly by state — cross-subsidy surcharges, wheeling charges, and banking policies differ across SERCs. The CERC First Amendment introduced multipliers for offshore wind and pumped hydro RECs, and a framework for VPPAs.
Electricity Market repository →CCTS, CCC trading, and the GEF trajectory
The Carbon Credit Trading Scheme is fully operational, setting active GEI targets for 740 entities across nine sectors. CCCs trade on regulated power exchanges under CERC oversight. The penalty for non-compliance is twice the average CCC price. The Grid Emission Factor determines the Scope 2 component of every industrial entity’s CCTS GEI. As RE penetration rises and the GEF falls, Scope 2 GEI falls automatically for any entity drawing from the grid.
Carbon Markets repository →RPO trajectory, RCO and the Energy Storage Obligation
Distribution companies and large open-access consumers face Renewable Purchase Obligations increasing each year toward 43.33% by 2029-30. The Renewable Consumption Obligation extends mandatory renewable consumption directly to large industrial Designated Consumers. The Energy Storage Obligation adds a parallel requirement to procure storage capacity. RECs satisfy RCO obligations but — crucially — do not reduce CBAM embedded emissions.
Renewable Obligations repository →Emission standards, fly ash and EIA for new capacity
Thermal power plants face stack emission standards for particulate matter, sulphur dioxide, and nitrogen oxides under the Air Act. The Fly Ash Utilisation Notification creates obligations linking power plants to cement and construction users within a specified radius. New power capacity — including renewable projects above threshold sizes — requires environmental clearance under the EIA Notification from MoEFCC.
Environmental Regulations repository →The power transition is the enabling condition — every other sector’s decarbonisation depends on it
Scale + Access
Carbon Market
Grid + H₂
PAT to CCTS Transition: Navigating the ESCert to CCC Conversion
Understanding the regulatory mechanics and financial implications of migrating from energy intensity targets under PAT to GHG emission intensity targets under CCTS.
India’s Coal Generation Decline and What it Means for Industrial CCTS Targets
How the 3% structural drop in coal generation cascades into the Grid Emission Factor and alters the Scope 2 compliance burden for 740 obligated entities.
CBAM Product Classification: A Guide to HS Codes for Indian Exporters
Mapping the exact customs nomenclature that triggers carbon border levies across steel, aluminium, cement, and fertiliser export categories.
Open Access Renewable Electricity: Calculating True Landed Costs by State
Breaking down cross-subsidy surcharges, wheeling charges, and banking limits to determine the actual gate cost of green power across key industrial states.
Decoding RCO and RPO: Compliance Strategies for Industrial Consumers
How to navigate overlapping mandates from the Renewable Purchase Obligation and the Renewable Consumption Obligation without double-counting costs.
Financing the Transition: Green Capital and Industrial Decarbonisation
Connecting climate targets to capital allocation: evaluating financing mechanisms for hard-to-abate sectors transitioning to low-carbon production routes.
Power sector decarbonisation is the foundation for every other sector’s transition — follow the links to see how it connects to each one.