India’s Grid Emission Factor: CEA Calculation, Current Values and CCTS Scope 2 Impact | Reclimatize.in
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Power and Carbon Markets · Carbon MarketsIndia’s Grid Emission Factor: How CEA Calculates It, What the Numbers Are, and Why Every CCTS-Obligated Plant Needs to Understand the Declining Trajectory
Scope 2 greenhouse gas emissions — indirect emissions from grid electricity consumption — form a significant portion of the GHG emission intensity of virtually every CCTS-obligated industrial plant. Their calculation under the CCTS depends on a single published number: the grid emission factor produced annually by India’s Central Electricity Authority. CEA Version 21.0 (December 2025) sets the provisional weighted average emission factor for FY 2024-25 at 0.710 tCO₂ per MWh — down from 0.727 in FY 2023-24 and 0.774 a decade ago. For plants planning their CCTS compliance strategy, renewable energy procurement decisions, and CBAM response, understanding what this number means, how it is calculated, and how fast it is falling is not optional background knowledge. It is foundational to every quantitative analysis that follows.
India’s grid emission factor is published annually by the Central Electricity Authority in its CO₂ Baseline Database for the Indian Power Sector. The database uses the CDM Executive Board’s “Tool to Calculate the Emission Factor for an Electricity System” (Version 7.0) as its calculation methodology. CEA Version 21.0, published December 2025, provides provisional FY 2024-25 emission factors. The weighted average emission factor (WAEF) for FY 2024-25 is 0.710 tCO₂/MWh, down from 0.727 tCO₂/MWh in FY 2023-24.
CEA publishes three distinct types of emission factor: the Weighted Average Emission Factor (average intensity of all grid generation including renewables), the Operating Margin (average intensity excluding low-cost must-run sources), and the Build Margin (average intensity of the most recently built 20% of capacity). The Combined Margin — a 50:50 weighted average of Operating Margin and Build Margin — is the factor used for calculating baselines in carbon offset project documentation. For FY 2023-24, the Combined Margin was 0.757 tCO₂/MWh and the Build Margin was 0.552 tCO₂/MWh.
Under the CCTS gate-to-gate methodology, a plant’s Scope 2 GHG emission intensity is calculated by multiplying total grid electricity consumed (in MWh) by the CEA-published grid emission factor. For a plant consuming 100 million kWh from the grid in FY 2024-25, Scope 2 emissions total approximately 71,000 tCO₂e — a significant portion of total GHG emission intensity for most energy-intensive industries. Every unit of renewable electricity substituted for grid electricity directly reduces this Scope 2 component.
The grid emission factor has declined by approximately 8.3% over the past decade as renewable energy’s share of total generation grows. India’s non-conventional RE generation in FY 2024-25 reached 255,009 million units — up from 225,830 million units in FY 2023-24. This growth in RE share structurally reduces the grid emission factor year by year. The long-term trajectory of the grid EF is downward: CCTS-obligated plants that delay renewable energy procurement will face both a rising compliance cost (as targets tighten) and a shrinking unit benefit from grid-to-renewable switching (as the grid itself gets cleaner).
For CCTS offset mechanism project developers — particularly renewable energy project developers earning Carbon Credit Certificates by displacing grid electricity — the combined margin (0.757 tCO₂/MWh for FY 2023-24) is the standard baseline factor. As this value declines year on year, the number of CCCs earned per MWh of renewable generation gradually decreases. The UCR and other voluntary carbon registries have adopted the CEA combined margin as the reference for Indian RE project baselines, recommending 0.757 tCO₂/MWh for 2024 vintage projects.
What the CEA CO₂ Baseline Database is and why it exists
India’s Central Electricity Authority has published a CO₂ Baseline Database for the Indian Power Sector since the mid-2000s, originally designed to support the Clean Development Mechanism (CDM) under the Kyoto Protocol. Under the CDM, renewable energy and energy efficiency projects in developing countries could earn Certified Emission Reductions (CERs) by demonstrating that they displaced fossil-fuel-based grid electricity. To calculate how much CO₂ their generation avoided, these projects needed an authoritative, independently calculated estimate of the emission intensity of the electricity they replaced — the grid emission factor.
CEA took on this role and has published the database annually ever since, using the CDM Executive Board’s internationally recognised methodology (“Tool to Calculate the Emission Factor for an Electricity System”, now on Version 7.0). The database covers all grid-connected thermal, nuclear and hydro power stations in India — currently more than 400 stations — with plant-level fuel consumption, generation, and emission data collected from station operators. Non-conventional renewable energy stations (wind, solar, small hydro under 25 MW, biomass) are not individually included in the database but their generation is accounted for in the weighted average emission factor calculation.
With the transition from CDM to CCTS, the CEA’s grid emission factor has acquired a new and more direct regulatory significance in India. Under the CCTS gate-to-gate methodology, every obligated industrial entity must calculate its Scope 2 indirect electricity emissions using the CEA-published grid emission factor. The database that began as a CDM support tool is now the foundational data source for India’s domestic compliance carbon market.
The three emission factor types — and which one matters for what
CEA publishes multiple emission factor values, and confusion between them is common among practitioners. Understanding what each type measures, how it is calculated, and what it is used for is essential for any entity engaged in CCTS compliance, carbon offset project development, or CBAM embedded emission calculations.
FY 2024-25 provisional (CEA V21.0)
The average CO₂ emission intensity of all grid-connected power stations in India, weighted by net generation. Calculated by dividing total CO₂ emissions from all grid-connected stations by total net electricity generated — including generation from thermal, nuclear, hydro, and (in total electricity terms) renewable energy sources. The WAEF represents what the average unit of electricity consumed from the Indian grid emitted in CO₂ terms. It is the most intuitive interpretation of the grid’s carbon intensity. From FY 2013-14 (0.774 tCO₂/MWh) to FY 2024-25 (0.710 tCO₂/MWh), the WAEF has declined by approximately 8.3% as RE’s share of generation grows.
Primary use: CCTS Scope 2 emission intensity calculations for obligated entities; general carbon accounting; CBAM Scope 2 embedded emission calculations; sustainability reporting.
FY 2023-24 approximate (excl. must-run sources)
The average CO₂ emission intensity of all grid-connected stations excluding low-cost, must-run generation sources — principally hydro, nuclear, and renewable energy stations, which operate at zero or near-zero marginal cost and are dispatched regardless of demand levels. The OM represents the emission intensity of the “dispatchable” thermal generation that actually responds to changes in demand. It is higher than the WAEF because the low-carbon sources that bring down the WAEF are excluded. India uses the “simple operating margin” approach (preferred under CDM methodology), which is straightforward to calculate from aggregate generation data. A plant displacing marginal thermal generation displaces the OM, not the WAEF — though for CCTS Scope 2 purposes, the WAEF is the applicable factor.
Primary use: Carbon offset project baseline calculations (one component of Combined Margin); understanding the marginal emission rate of additional grid electricity consumption.
FY 2023-24 (CEA V20.0 — first to include RE in BM)
The average CO₂ emission intensity of the most recently built capacity in the grid — specifically, the most recent additions representing 20% of total system net generation, whichever represents a larger sample. The BM captures the emission profile of the generation that new capacity additions are replacing or supplementing. In India’s case, recent capacity additions have been heavily weighted toward renewable energy — solar and wind — which has dramatically reduced the BM. CEA Version 20.0 (December 2024) was the first to include renewable energy generation in the BM calculation, causing the BM to fall sharply to 0.552 tCO₂/MWh for FY 2023-24 (from significantly higher values when only thermal “new build” was counted).
Primary use: Carbon offset project baseline calculations (one component of Combined Margin); understanding the direction of new capacity additions and their emission profile.
FY 2023-24 (CEA V20.0); UCR 2024 vintage baseline
The 50:50 weighted average of the Operating Margin and the Build Margin. The Combined Margin is the standard baseline emission factor for CDM and voluntary carbon market offset project calculations in India — used specifically to calculate how many CERs or CCCs a renewable energy project earns by displacing grid electricity. The CM sits between the OM (higher) and BM (lower), reflecting both the current operating reality of the grid and the direction of new additions. For FY 2023-24, the CM of 0.757 tCO₂/MWh is the value recommended by the Universal Carbon Registry for 2024 vintage Indian renewable energy projects. As BM continues to fall with increasing RE additions, the CM will trend down over time.
Primary use: Baseline emission factor for CCTS Offset Mechanism project documentation; CDM project calculations; voluntary carbon market RE project baselines globally.
The historical trend — a decade of declining carbon intensity
India’s grid emission factor has been declining steadily as renewable energy capacity has expanded faster than overall electricity demand growth. CEA Version 21.0 documents this trajectory over the past decade.
Two anomalies stand out in this trend. First, FY 2023-24 shows a slight rise from FY 2022-23 (0.727 vs 0.716) despite continued renewable expansion. CEA’s explanation in Version 20.0 is that coal generation increased by approximately 9.6% in that year to meet accelerating demand — with coal generation’s incremental growth exceeding renewable generation’s growth in proportional terms. This illustrates a structural tension in India’s electricity sector: even as RE capacity scales rapidly, rising absolute demand can force more coal dispatch, temporarily lifting the WAEF. Second, the COVID-influenced dip in FY 2020-21 (0.703) reflects reduced industrial demand meaning a lower ratio of coal dispatch to total generation in that anomalous year.
The provisional FY 2024-25 figure of 0.710 tCO₂/MWh — based on RE generation reaching 255,009 million units — represents a resumption of the structural decline. India’s 2035 NDC targets, under which non-fossil electricity capacity reaches 60% and total non-fossil generation grows substantially, will continue to drive the WAEF lower through the 2030s. CEA’s long-term trajectory analysis suggests the WAEF could fall below 0.600 tCO₂/MWh by 2030-31 under ambitious RE deployment scenarios.
How the grid emission factor enters CCTS Scope 2 calculations
Under the CCTS gate-to-gate methodology, a CCTS-obligated plant’s GHG emission intensity (GEI) is expressed in tCO₂e per unit of production output. The GEI numerator includes Scope 1 direct emissions from fuel combustion and industrial processes, and Scope 2 indirect emissions from grid electricity consumption. Scope 2 is calculated as:
Scope 2 GHG Emissions (tCO₂e) = Grid electricity consumed (MWh) × Grid emission factor (tCO₂/MWh)
Where the grid emission factor is the CEA-published Weighted Average Emission Factor for the relevant fiscal year.
The grid emission factor used is the WAEF — the weighted average across all grid generation. This is the most appropriate factor for Scope 2 consumption-based accounting because it represents the average carbon content of a unit of electricity withdrawn from the grid. The Operating Margin or Combined Margin are not used for CCTS Scope 2 — those factors are for project-based offset credit calculations.
At a CCC price of Rs 300/tCO₂e (conservative early-market estimate), the 42,600 tCO₂e Scope 2 reduction from a 30% renewable switch translates to approximately Rs 1.28 crore per year in CCC value. At Rs 500/tCO₂e, this becomes approximately Rs 2.13 crore per year. At the CBAM equivalent of €80/tCO₂e (approximately Rs 7,200/tCO₂e), the same Scope 2 reduction is worth approximately Rs 30.7 crore per year in avoided CBAM certificate cost — for a plant exporting to the EU. This comparison makes clear that CBAM currently provides a far stronger financial signal for Scope 2 decarbonisation than the CCTS alone — and that integrated analysis across both frameworks changes the investment return calculation dramatically.
The declining EF and its strategic implications — acting earlier is worth more
The grid emission factor is declining structurally and durably. Every year that passes, the CEA WAEF moves lower as more renewable generation enters the Indian electricity system. This creates a counterintuitive but important strategic dynamic for industrial plants managing CCTS compliance.
Consider the calculation above. A plant switches 30% of its grid consumption to green open access in FY 2024-25 and avoids 42,600 tCO₂e in Scope 2 emissions. If the same plant makes the same switch five years later, in FY 2029-30, the WAEF will be lower — perhaps 0.580 tCO₂/MWh under optimistic RE deployment scenarios. The same 30% renewable switch would then avoid only approximately 34,800 tCO₂e in Scope 2. Early action captures more CCC value and more CBAM value per unit of renewable electricity consumed — simply because the grid emission factor is higher now than it will be in future.
This “declining EF urgency” is a structural feature of any carbon market that applies to Scope 2 electricity emissions during an energy transition. It has been observed in the EU context: as the EU ETS drove coal out of European electricity generation, the grid emission factor fell and the Scope 2 emission intensity of the same industrial electricity consumption declined — meaning the abatement potential from any given unit of renewable energy substitution also declined. Indian CCTS-obligated plants are at the early stages of a similar dynamic, and the financial logic of earlier renewable procurement — both for CCTS credit accumulation and for CBAM Scope 2 compliance documentation — is strongest in the next three to five years while the WAEF remains relatively high.
CEA Version 20.0 (December 2024) introduced a significant methodological change: for the first time, non-conventional renewable energy generation was included in the Build Margin calculation. Previously, the BM was calculated only from conventional capacity additions (thermal and large hydro). Because recent years have seen predominantly RE capacity being added, including RE in the BM dramatically reduced it — from values above 0.700 in earlier versions to 0.552 tCO₂/MWh in V20.0.
For renewable energy developers earning CCCs through the CCTS Offset Mechanism, this change has a direct financial impact. The Combined Margin, which is the baseline factor for carbon credit calculations, fell as a result of the lower BM — from approximately 0.80 tCO₂/MWh (which had been a commonly assumed proxy for CDM calculations pre-V20.0) to 0.757 tCO₂/MWh in V20.0. A solar project of 100 MW generating approximately 180,000 MWh per year would earn approximately 136,260 CCCs per year at the new CM of 0.757 tCO₂/MWh, compared with roughly 144,000 CCCs at the old 0.80 estimate. The difference — approximately 7,740 CCCs per year or 5.4% fewer — compounds over a 10-year crediting period. Offset project developers should model their CCC revenue projections using the most current CEA CM value and should assume the CM will continue declining, reducing per-MWh credit earnings over the project lifetime.
Version history and the publication cycle
CEA has published the CO₂ Baseline Database annually since the mid-2000s, with version numbers incrementing each year. The publication schedule is approximately:
| CEA Database Version | Published | Data coverage | Notable changes | WAEF (tCO₂/MWh) |
|---|---|---|---|---|
| Version 19.0 | January 2024 | Up to FY 2022-23 | — | 0.716 (FY 2022-23) |
| Version 20.0 | December 2024 | Up to FY 2023-24 | First to include RE in Build Margin calculation | 0.727 (FY 2023-24) |
| Version 21.0 | December 2025 | Up to FY 2024-25 (provisional) | RE generation: 255,009 MU; RE installed: 220,096 MW | 0.710 (FY 2024-25, provisional) |
| Version 22.0 | ~December 2026 | Up to FY 2025-26 | Expected continued WAEF decline as RE expands further | Projected: ~0.685–0.695 |
For CCTS compliance purposes, the CEA WAEF for the compliance year being reported is the applicable factor. CCTS-obligated entities should note that BEE will specify the exact grid emission factor for each compliance year in its detailed procedures — likely using the most recently published CEA value for the same fiscal year or the preceding year. Entities should verify the specific version and year specified in the BEE detailed compliance procedure for each reporting period rather than assuming they use the most current CEA value at the time of reporting.
Frequently Asked Questions
Which CEA emission factor is used for CCTS Scope 2 calculations?
The Weighted Average Emission Factor (WAEF) — the average carbon intensity of all grid-connected generation weighted by net output — is the appropriate factor for CCTS Scope 2 consumption-based accounting. For FY 2024-25, this is 0.710 tCO₂/MWh (provisional, CEA Version 21.0). The Operating Margin and Combined Margin are used for carbon offset project baseline calculations, not for consumption-based Scope 2 accounting. CCTS-obligated entities should confirm with BEE’s detailed compliance procedure which specific CEA version and year they are required to use for each reporting period.
Why did the grid emission factor rise in FY 2023-24 despite more renewable energy being added?
India’s overall electricity generation grew substantially in FY 2023-24, with coal generation increasing by approximately 9.6% to meet rising industrial and residential demand. Although renewable generation also increased (to 225.83 billion units from 203.55 billion units), the absolute increase in coal-based generation in that year was proportionally large enough to shift the weighted average upward from 0.716 to 0.727 tCO₂/MWh. This illustrates that the grid emission factor is a product of both the renewable share and the absolute level of fossil generation — which can temporarily move counter to the structural trend if demand growth is particularly strong.
Does renewable energy physically consumed at my plant reduce my Scope 2 GHG intensity even if the CEA WAEF is what BEE uses for calculation?
Yes. The grid emission factor applies to electricity sourced from the grid. If a plant consumes renewable electricity through a green open access PPA or on-site captive generation, that electricity is not sourced from the grid and the WAEF does not apply to it — its emission factor is zero (for solar, wind, and hydro). Only the electricity physically sourced from the distribution grid is multiplied by the WAEF. This is why actual renewable procurement is required to reduce CCTS Scope 2, not just REC purchases — RECs represent renewable generation elsewhere in the grid but the underlying electricity consumed at the plant is still grid-sourced and carries the WAEF.
How is the grid emission factor relevant to CBAM embedded emission calculations?
CBAM calculates embedded emissions including Scope 2 electricity emissions for CBAM-covered products. The methodology for calculating Scope 2 under CBAM uses an electricity emission factor for the country or region of production — in India’s case, the CEA WAEF is the reference. A steel plant, aluminium smelter or fertiliser complex exporting to the EU must include Scope 2 electricity emissions in its CBAM declaration. The lower the Scope 2 — either through a lower grid EF or through actual renewable consumption — the lower the embedded emission value and therefore the lower the CBAM certificate obligation for the EU importer. EU importers can and should request verified actual data from Indian suppliers showing the renewable electricity consumption share, rather than using EU default values which may be based on the average national WAEF without accounting for on-site renewable generation.
What happens to the CCC value of a renewable energy offset project as the grid emission factor falls?
Each year, the Combined Margin (the baseline factor for CCTS offset projects) falls as more RE is added to the grid. A solar plant registered under the offset mechanism earns CCCs equal to its annual generation multiplied by the CM. If the CM falls from 0.757 tCO₂/MWh today to 0.650 tCO₂/MWh in five years, the same solar plant earns approximately 14% fewer CCCs per year from the same generation — even if the CCC price is unchanged. This structural decline in offset credit yield is an important consideration for project developers modelling long-term CCC revenue. It creates an incentive for early registration and operation — projects that begin generating CCCs now capture the higher baseline before it declines further.