India's Coal Power Structural Decline: Why the GEF Trajectory Is the Most Important Number for Industrial Carbon Compliance
India's power sector CO₂ fell in FY25, marking only the second time this has happened in half a century. Looking ahead, the Central Electricity Authority projects non-fossil generation to rise from 25 percent to 44 percent by FY2029-30. For every industrial entity connected to the grid, this trajectory is delivering a free, automatic, and passive Scope 2 GEI improvement of approximately 0.020 to 0.030 tCO₂/t each year, without requiring any capital investment. Understanding this trajectory forms the true foundation of every CCTS compliance plan.
Key Takeaways
- India's power sector CO₂ emissions officially fell in FY 2024-25, marking only the second time this has occurred in the past half-century, according to Carbon Brief analysis utilizing Central Electricity Authority and Ministry of Power data. The first structural decline happened in 2020-21, driven strictly by an industrial shutdown during the pandemic. The FY25 decline, however, was driven by renewable generation growth outpacing demand growth. This marks the first time in India's post-liberalisation energy history that renewable additions created a genuine displacement of coal generation at the margin rather than merely adding on to a growing total.
- The CEA's optimal generation mix projection for FY2029-30 shows the non-fossil generation share rising steeply from approximately 25 percent of total generation in FY2024-25 to roughly 44 percent by FY2029-30. This trajectory implies the Grid Emission Factor (GEF) will decline from the current WAEF of 0.710 tCO₂/MWh down toward approximately 0.50 tCO₂/MWh by 2030. Each year that this trajectory holds steady, the passive Scope 2 GEI benefit for grid-connected industrial consumers grows, lowering their CCTS compliance cost automatically.
- The coal power capacity utilisation factor, often called the plant load factor or PLF, for Indian thermal power plants has been steadily declining. It has fallen from an average of approximately 64 percent in FY2019-20 toward approximately 58 to 60 percent in FY2024-25 as renewable generation has increasingly met incremental demand. New coal capacity additions, which are still occurring due to grid reliability and baseload requirements, are being commissioned into an environment of falling average utilisation. This creates a severe stranded asset risk for the least efficient coal plants and the oldest segments of the fleet. India's average coal plant age is now approximately 22 years, with a significant tail of plants exceeding 30 years of operation.
- For industrial CCTS compliance planning, a declining GEF has a highly counterintuitive implication. It makes BEE's GEI targets progressively easier to meet for grid-connected entities, even without making their own abatement investments. For instance, a steel plant consuming 1,000 kWh of grid electricity per tonne of crude steel saw its Scope 2 GEI contribution drop from 0.900 tCO₂/t at the 2020 GEF baseline to 0.710 tCO₂/t at the current 2026 GEF. This represents a passive improvement of 0.190 tCO₂/t without any action taken by the plant. If BEE's Phase 1 GEI target for steel demands a 3 percent intensity reduction per year, a plant with 30 percent grid electricity in its total energy mix may achieve full compliance automatically through GEF decline alone, leaving the CCTS compliance effort to focus entirely on Scope 1 reduction.
- The structural decline of coal power has direct implications for CCTS carbon market supply through the power sector offset mechanism. Displacing coal with renewable generation reduces the total GHG emission intensity of the power sector, effectively reducing the WAEF that enters industrial Scope 2 calculations. Simultaneously, it enables renewable energy projects to generate higher-value offset CCCs because their avoided emission baseline against the coal-dominated grid registers higher. As the GEF falls, each new renewable generation project's offset CCC credit per MWh inevitably decreases, but the CCTS Scope 2 relief for every industrial consumer simultaneously increases. The net effect on CCC market supply and demand is highly complex and acts as a major factor creating uncertainty in Phase 1 price formation.
- The coal power structural decline generates severe stranded asset risk for industrial companies operating captive coal power plants that still have 10 to 20 years of remaining life. A captive coal CPP at 0.90 to 1.05 tCO₂/kWh generating electricity that is increasingly more expensive, on a fully-loaded basis, than open access renewable alternatives faces a dual problem of rising carbon compliance costs under CCTS Scope 2 GEI and rapidly declining economic justification. The PLF of captive coal CPPs is already dropping as companies wisely switch marginal load to cheaper open access RE. Captive coal CPPs sitting in the 15 to 25 year age bracket represent the sector where stranded asset decisions will become most acute during the 2028 to 2032 period.
Throughout half a century of rapid industrial development, India's power sector carbon emissions had fallen only once before FY25. That single occurrence was during the extraordinary demand collapse of the pandemic year in FY2020-21. Every other year in the post-Independence history of India's power sector saw emissions rise steadily, driven by the consistent growth in electricity demand from an industrialising economy and the heavily coal-dominated generation mix that powered it. The FY25 decline is therefore not merely an interesting data point; it serves as a structural signal that the relationship between economic growth and power sector CO₂ is finally beginning to decouple in India, manifesting a reality that decades of policy aspiration had promised but struggled to deliver.
Carbon Brief's analysis of the FY25 data attributed the decline directly to renewable generation additions, primarily solar, growing faster than national demand. This dynamic is not the same as actively shutting down coal-fired generation. Most of India's coal plants continued to operate, but at reduced utilisation rates as renewable energy smoothly absorbed their incremental generation share. However, the direction of travel is now firmly established: renewables are absorbing incremental demand growth, coal PLFs are declining, and absolute coal generation is stagnating. The CEA's own optimal mix projection confirms this trajectory, forecasting the non-fossil generation share to rise from 25 percent in FY24-25 to 44 percent in FY29-30. Under this scenario, coal generation grows slightly in absolute volume but declines significantly as a percentage of the growing total.
The GEF Arithmetic: What the Trajectory Means for Each Industrial Sector
GEI Scope 2 (FY2024-25, WAEF 0.710): 14,500 × 0.710 ÷ 1,000 = 10.3 tCO₂/t aluminium
GEI Scope 2 (FY2029-30, WAEF ~0.50): 14,500 × 0.50 ÷ 1,000 = 7.25 tCO₂/t aluminium
Passive improvement (no RE investment): 10.3 - 7.25 = 3.05 tCO₂/t aluminium
At 500,000 t/yr production: Total passive improvement = 1.525 Mt CO₂e/year by FY2029-30
At an expected CCTS CCC price of Rs 750/tCO₂e: Annual CCTS compliance value = Rs 1,144 crore
Steel plant consuming 1,000 kWh/t grid electricity (auxiliary operations):
GEI Scope 2 (FY2024-25): 1,000 × 0.710 ÷ 1,000 = 0.710 tCO₂/t
GEI Scope 2 (FY2029-30): 1,000 × 0.50 ÷ 1,000 = 0.500 tCO₂/t
Passive improvement per tonne: 0.210 tCO₂/t steel
At 5 MMT/yr production: 1.05 Mt CO₂e passive improvement leading to a Rs 788 crore/yr CCTS compliance value
Let's look at what this passive benefit actually means in financial terms. A 500,000 tonne per year aluminium smelter running entirely on grid electricity, taking absolutely no action on renewable procurement, will nevertheless see its CCTS Scope 2 GEI improve by approximately 3.05 tCO₂/t between 2025 and 2030. This happens purely because the national grid is decarbonising around it. Based on projected Phase 1 CCC prices, this passive improvement holds a CCTS compliance value of approximately Rs 1,144 crore per year by FY2029-30. This is not a small number. It represents a massive compliance cost avoided and potentially generates a CCC surplus that can be sold on the open market to less-efficient compliance entities.
| Sector | Grid Electricity Intensity | GEI Scope 2 at WAEF 0.710 | GEI Scope 2 at WAEF ~0.50 | Passive Improvement | CBAM Impact |
|---|---|---|---|---|---|
| Primary Aluminium (grid) | 14,500 kWh/t | 10.3 tCO₂/t | 7.25 tCO₂/t | Minus 3.05 tCO₂/t | ~€244/t CBAM reduction at €80/tCO₂e |
| Steel (grid auxiliary) | 800 to 1,000 kWh/t | 0.57 to 0.71 tCO₂/t | 0.40 to 0.50 tCO₂/t | Minus 0.17 to 0.21 tCO₂/t | Not direct; CBAM steel focuses on Scope 1 only |
| Fertilisers (grid power) | 500 to 700 kWh/t urea | 0.36 to 0.50 tCO₂/t | 0.25 to 0.35 tCO₂/t | Minus 0.11 to 0.15 tCO₂/t | ~€9 to 12/t CBAM reduction (Scope 2 is included for fertilisers) |
| Cement (grid auxiliary) | 100 to 120 kWh/t | 0.071 to 0.085 tCO₂/t | 0.050 to 0.060 tCO₂/t | Minus 0.021 to 0.025 tCO₂/t | Not currently CBAM-covered |
The Captive Coal CPP Paradox: Why a Declining Grid GEF Makes Captive Coal Increasingly Indefensible.
Industrial companies utilizing captive coal power plants determine their Scope 2 GEI using the captive plant's actual emission factor, which typically hovers around 0.90 to 1.05 tCO₂/kWh, rather than relying on the national WAEF. As the national WAEF declines toward 0.50 tCO₂/MWh by 2030, the glaring gap between the captive coal CPP emission factor and the grid GEF widens dramatically, moving from approximately 0.19 to 0.34 tCO₂/kWh today up to approximately 0.40 to 0.55 tCO₂/kWh by 2030. A company heavily reliant on a captive coal CPP will discover that its CCTS Scope 2 GEI target, which is set against a sector average that includes automatically improving grid-connected entities, becomes progressively tighter. This tightening happens not because BEE is setting stricter rules, but because the grid-connected peer group improves without effort while the CPP-dependent company stands still. This represents the captive coal CPP's hidden compliance risk: while it may temporarily insulate the company from electricity price volatility, it actively exposes the company to a progressive CCTS compliance disadvantage as the broader grid decarbonises.
Coal power stranded asset risk and its carbon market implications
India's coal power fleet stranded asset risk is essentially a carbon market event just as much as a power sector event. Plants that become commercially uneconomic, either because renewable electricity proves cheaper at the margin or because rising carbon compliance costs make coal generation painfully expensive for captive industrial users, will inevitably exit the market. This sequence of exit will be determined primarily by age, operating efficiency, and the raw cost of continued operation relative to cleaner alternatives. The carbon market implications tied to this exit process are twofold.
First, as legacy coal plants systematically exit, the total supply of coal-fired generation naturally falls, which actively accelerates the GEF decline beyond what simple renewable additions alone could produce. Each single percentage point reduction in coal's overall share of total generation translates directly into a GEF reduction, a shift that financially benefits every grid-connected industrial consumer's CCTS Scope 2 position. Consequently, the CEA's optimal mix projection may actually understate the pace of GEF decline if coal plant retirements happen to accelerate beyond current projections, driven perhaps by high coal prices from international shocks, mounting CCTS compliance pressure, or state DISCOMs aggressively shifting toward cheaper renewable procurement.
Second, coal plant retirement creates highly valuable physical assets, including cleared land, heavy grid connections, robust water infrastructure, and a skilled local labour force. In many cases, these assets can be efficiently repurposed for large-scale renewable or storage development. India's JETP (Just Energy Transition Partnership) commitment specifically includes dedicated programmes aimed at repowering old coal sites with renewable capacity and actively retraining coal workers. For industrial companies burdened with captive coal plants fast approaching their end of life, the repowering option, which involves replacing a retiring coal CPP with captive solar or wind on the exact same land parcel utilizing the existing grid connection, may represent the absolute most capital-efficient pathway to achieving clean electricity at the plant level.
Frequently Asked Questions
Is India's coal power decline structural or cyclical?
The FY25 decline reflects deeply structural causes, primarily renewable generation additions rapidly outpacing demand growth, rather than the cyclical demand suppression experienced during the pandemic year in FY20-21. The CEA's optimal mix projections, which act as forward-looking capacity planning documents, clearly confirm this structural direction by charting the non-fossil generation share rising from 25 percent to 44 percent by FY2029-30. That specific trajectory is fundamentally driven by a committed pipeline of renewable and nuclear capacity additions, the rapidly declining cost curves of renewable generation, and the central government's aggressive 500 GW non-fossil capacity target. Reversing this trend toward coal-dominant generation growth would require either an absolute collapse in renewable capacity additions or an unexpectedly massive jump in electricity demand that renewables simply cannot meet. Neither scenario aligns with current project pipeline data or credible demand forecasts.
Does the coal power decline affect CCTS target setting for industrial entities?
BEE sets GEI intensity reduction targets based on a given sector's historical GEI trajectory alongside the government's broader sectoral decarbonisation ambitions. The declining GEF absolutely reduces the Scope 2 GEI of grid-connected entities automatically. However, BEE's target-setting process is fully expected to account for this automatic improvement when calibrating future phase GEI reduction percentages. If BEE determines that grid-connected entities are effortlessly over-achieving their Phase 1 GEI targets purely due to passive GEF decline, Phase 2 targets are highly likely to be set at a much higher ambition level. This approach effectively captures the passive GEF benefit directly within the target rather than allowing it to generate indefinitely large CCC surpluses. Therefore, while the GEF trajectory greatly benefits compliance-cycle entities in Phase 1, it is likely to be partially offset by far tighter targets as Phase 2 rolls out.
What does the coal power decline mean for the CCTS CCC market price?
The coal power decline reduces the Scope 2 GEI of grid-connected entities automatically, effectively reducing their net demand for compliance CCCs. This dynamic acts as a major supply-and-demand reducing factor for the entire CCC market. If entities require fewer CCCs because their GEI is improving passively, the Phase 1 compliance demand sits lower than it would in a scenario without GEF decline. When combined with the heavy offset CCC supply generated from new renewable projects, which earn CCCs against the coal-displaced GEF baseline, the coal power decline creates a structural supply-side surplus in Phase 1. This surplus is widely expected to keep opening CCC prices pinned at the lower end of the Rs 600 to 900 per tonne range. It is worth noting that Phase 2 dynamics, when the steel, fertiliser, and power sectors enter with much tighter targets, will look vastly different.
Sources
- Carbon Brief, India's power sector CO₂ falls for only second time in half a century, September 2025
- Central Electricity Authority, CO₂ Baseline Database V21.0 December 2025 detailing WAEF 0.710 tCO₂/MWh
- Central Electricity Authority, Optimal Generation Capacity Mix for FY2029-30 and non-fossil generation share projections
- Ministry of Power, Installed capacity data from January 2026 showing 520.5 GW total with 52.57% non-fossil
- IEEFA, India coal power plant utilisation and stranded asset analysis, 2025
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