Home › Research › CCTS Compliance Aluminium Smelters
Aluminium · CCTSCCTS Compliance for Indian Aluminium Smelters: Gazette Targets, Four Abatement Levers, and the Triple Value of Renewable Electricity
India’s thirteen primary aluminium smelters are operating under legally binding Greenhouse Gas Emission Intensity targets gazette-notified by MoEFCC on 8 October 2025. The targets are mandatory, quantified at the facility level, and carry a penalty of twice the average CCC trading price for every tonne of shortfall that is not covered by purchased credits. Vedanta Jharsuguda must reduce its GEI from 13.4927 to 12.8259 tCO₂/t by FY2026-27; BALCO must move from 15.7129 to 14.8087; Mahan Aluminium from 15.6301 to 14.7354. The sector as a whole faces a ~5.8% GEI reduction from baseline over two years. Four abatement levers are available — renewable electricity procurement, potline energy efficiency, anode effect reduction, and thermal efficiency improvements — but only one of them resolves three regulatory obligations simultaneously. Every unit of renewable electricity consumed at the smelter simultaneously reduces CCTS Scope 2 GEI, eliminates CBAM Scope 2 embedded emissions for EU-bound exports, and satisfies the Renewable Consumption Obligation. The CCC revenue, CBAM cost avoidance, and RCO compliance value together create a total return of approximately Rs 7.88 per kWh of coal replaced — materially above the landed cost of green open access solar.
The Greenhouse Gas Emission Intensity Target Rules, 2025, gazette-notified on 8 October 2025, set legally binding GEI targets for 13 primary aluminium smelters for FY2025-26 and FY2026-27, using FY2023-24 as the baseline. The three largest smelters are: Vedanta Jharsuguda Smelter II (1,238,336 t baseline production; GEI 13.4927 → 12.8259 by FY2026-27); BALCO Korba (591,844 t; GEI 15.7129 → 14.8087); Mahan Aluminium Singrauli (374,049 t; GEI 15.6301 → 14.7354). A secondary aluminium sub-sector was added in a further notification on 16 January 2026. The sector average GEI for primary smelters is approximately 16.98 tCO₂/t — above the global average of approximately 15.1 tCO₂/t — principally because Indian smelters draw power predominantly from captive coal power plants.
The CCC calculation is defined in the Official Gazette. CCCs earned = (GEI Target minus GEI Achieved) × production in tonnes of equivalent product. CCCs to purchase = (GEI Achieved minus GEI Target) × production. Environmental Compensation = 2× the average CCC trading price for that compliance year × shortfall tonnes. At a CCC price of Rs 800/tCO₂e, a smelter that misses its target by 0.3 tCO₂/t on 591,844 tonnes of production faces a penalty or purchase cost of approximately Rs 142 crore for that year’s shortfall. Conversely, a smelter that over-performs by 1.0 tCO₂/t on the same production earns 591,844 CCCs worth approximately Rs 473 crore at Rs 800/CCC — a material P&L contribution from a compliance mechanism that was zero two years ago.
Of the four abatement levers available, renewable electricity has the highest GEI impact and the highest combined regulatory value. The GEI formula covers Scope 1 (fuel combustion and process) and Scope 2 (captive power plant emissions and grid electricity) on a gate-to-gate basis. A smelter replacing coal-sourced captive power with renewable electricity at zero emission factor reduces its Scope 2 GEI by approximately 0.710 tCO₂ per MWh of power switched (at the CEA grid emission factor), or approximately 0.9 tCO₂ per MWh when captive coal CPP is replaced (captive CPP typically emits 0.85–1.0 tCO₂/MWh). At typical smelter electricity intensity of 14 to 15 MWh per tonne of aluminium, a 25% renewable substitution delivers approximately 3 to 3.5 tCO₂/t GEI reduction — enough to move most Indian smelters from above-target to materially below-target, generating CCC surplus.
The unique regulatory feature of the aluminium sector under the CBAM framework is that CBAM covers Scope 1 AND Scope 2 emissions — unlike steel, where only Scope 1 is currently in scope. For Indian aluminium smelters exporting to the EU, every tonne of coal-sourced captive power replaced by renewable electricity reduces CBAM embedded Scope 2 emissions simultaneously with CCTS Scope 2 GEI. At an EU ETS price of approximately €65/tCO₂e, replacing 1 MWh of coal CPP power (0.9 tCO₂/MWh) with RE eliminates approximately €58.50 per MWh in CBAM embedded emission cost. At India’s typical smelter electricity intensity of 14 MWh/t Al, full RE conversion would eliminate approximately €819 per tonne of CBAM certificate cost for Scope 2 alone — reducing CBAM liability from approximately €1,000+ per tonne to approximately €100–200 per tonne from Scope 1.
Hindalco announced a Rs 21,000 crore smelter expansion at Aditya Aluminium in Sambalpur, Odisha, on 27 January 2026, adding 360,000 tpa of capacity. The Aditya complex already has one of the lowest GEI baselines among Indian smelters, reflecting its modern AP37 potline technology. This expansion signals Hindalco’s confidence in the domestic aluminium demand trajectory, but also underscores the scale at which new capacity must be designed with RE power integration from inception — since the GEI targets will tighten materially in CCTS Phase 2 (from FY2027-28) and since CBAM certificate costs for Scope 2 will compound over time as the EU ETS price rises.
The gazette targets — what each major smelter must achieve
The GHG Emission Intensity Target Rules, 2025, gazette-notified by MoEFCC on 8 October 2025, represent India’s first legally binding facility-level carbon targets for any industrial sector. For aluminium, 13 primary smelters and associated refining units received quantified two-year trajectories covering FY2025-26 and FY2026-27. The baseline year is FY2023-24; there are no provisions for retrospective adjustment of the baseline based on production changes during the compliance years (production can change — the GEI target per tonne stays fixed).
| Smelter | State | Baseline production FY2023-24 (t) | Baseline GEI (tCO₂/t) | FY2025-26 target | FY2026-27 target | Total reduction (%) |
|---|---|---|---|---|---|---|
| Vedanta Ltd, Jharsuguda Smelter II (ALMOE001OD) | Odisha | 1,238,336 | 13.4927 | 13.2260 −1.98% | 12.8259 −4.94% total | 4.94% |
| Mahan Aluminium Plant, Singrauli (ALMOE002MP) | Madhya Pradesh | 374,049 | 15.6301 | 15.2722 −2.29% | 14.7354 −5.73% total | 5.73% |
| BALCO, Korba (ALMOE003CG) | Chhattisgarh | 591,844 | 15.7129 | 15.3512 −2.30% | 14.8087 −5.75% total | 5.75% |
| Hindalco Hirakud Smelter | Odisha | 178,830 | 19.2759 | 18.7315 −2.82% | 17.9150 −7.06% total | 7.06% |
| Sector average (primary smelter) | All states | ~16.98 tCO₂/t (vs global avg ~15.1) | ~2% reduction target | ~2.4–2.6% further | ~5.8% over two years | |
The structure of these targets reflects a deliberate site-specific benchmarking approach rather than a uniform sector cut. Plants with lower baseline GEI — primarily those with newer potline technology, like Vedanta Jharsuguda with its Series IV potlines — face smaller absolute reduction requirements because they have already invested in efficient technology. Plants with older technology and higher baseline GEI — like Hindalco Hirakud with its legacy cell design dating to 1971 — face steeper targets in percentage terms, reflecting greater abatement potential. This benchmarking is the same principle India used in the PAT scheme, extended now to direct GHG emission intensity rather than energy intensity.
The sector-wide implication of these numbers is important. Taken together, the aluminium primary smelter sub-sector must reduce its aggregate GEI by approximately 5.8% over two years relative to its FY2023-24 baseline. CEEW analysis has confirmed that most of this abatement lies in the negative-cost or low-cost zone of the marginal abatement cost curve — energy efficiency improvements and REC-equivalent RE procurement that reduce electricity costs simultaneously. This means Phase 1 compliance, while mandatory and financially real, should be achievable at net-positive economics for well-managed smelters. The financial pressure accumulates in Phase 2 (FY2027-28 onwards), when targets will need to tighten to align with the 2035 NDC trajectory.
The CCC calculation — how surplus and deficit are quantified
The Official Gazette defines the CCC calculation precisely. Understanding it is essential for any smelter treasury team modelling CCTS compliance costs or revenue.
Illustrative surplus — Vedanta Jharsuguda, FY2026-27: Assume Vedanta achieves GEI of 11.5 tCO₂/t through significant RE procurement (25% RE blend on 1.24 Mt production).
Target: 12.8259 tCO₂/t; Achieved: 11.5 tCO₂/t; Surplus: 1.3259 tCO₂/t × 1,238,336 t = 1,641,613 CCCs. At Rs 800/CCC: Rs 131.3 crore CCC revenue for a single year’s over-performance at one plant.
Illustrative deficit — BALCO, FY2025-26: Assume BALCO achieves 15.70 tCO₂/t (misses by 0.35 tCO₂/t on target of 15.3512).
Deficit: 0.3488 tCO₂/t × 591,844 t = 206,425 CCCs to purchase or 412,850 tCO₂e Environmental Compensation at 2× price.
At Rs 800/CCC (purchase): Rs 165 crore. At Rs 800/CCC (penalty): Rs 330 crore (2× rate).
The asymmetry between the purchase option (1× CCC price) and the Environmental Compensation penalty (2× CCC price) creates a clear incentive structure. An entity that anticipates a shortfall should purchase CCCs on the market at the going price rather than default to the Environmental Compensation route, which costs double. This means that entities with structural difficulties in meeting their targets — perhaps because their captive power plant has been delayed in RE transition — have a rational incentive to be net buyers of CCCs in the trading market, supporting price formation and providing liquidity for over-achieving smelters to monetise their surplus.
Four abatement levers — ranked by impact and deployment speed
Aluminium smelting consumes approximately 14 to 15 MWh of electricity per tonne of aluminium. The Scope 2 component of GEI — indirect emissions from electricity — is the dominant contributor to most Indian smelters’ GEI above the global average. Coal CPP power carries an emission factor of approximately 0.85 to 1.0 tCO₂/MWh; the CEA national grid emission factor for FY2024-25 is 0.710 tCO₂/MWh. Replacing 1 MWh of coal CPP power with RE at near-zero emission factor reduces the Scope 2 GEI by 0.85 to 1.0 tCO₂/MWh × the share of that MWh in total per-tonne electricity use. At 14.5 MWh/t specific electricity consumption, a 25% RE blend reduces GEI by approximately 3.0 to 3.6 tCO₂/t. Three procurement routes exist under GEOA: captive (own plant, ≥26% equity, CSS/AS waived); group captive (consortium ownership, same waiver); or third-party open access (all charges apply but competitive landed cost in Odisha and CG). Captive or group captive is the preferred route for long-term cost and regulatory certainty. Odisha and Chhattisgarh — where Vedanta, Hindalco Hirakud, and BALCO are located — have state policies that completely waive CSS and AS for solar and wind regardless of procurement category, making open access solar the most cost-competitive in India.
Perfluorocarbon gases — CF₄ and C₂F₆ — are generated during anode effect events in the aluminium electrolysis cell. Their global warming potentials are 6,500 and 9,200 times that of CO₂ respectively. Even rare anode effects can contribute 1 to 2 tCO₂e/t Al to the GEI. Modern point feeder systems combined with advanced bath chemistry control (alumina concentration management, bath height optimisation) virtually eliminate anode effect frequency. The capital investment is moderate — primarily in point feeder upgrades, advanced process control systems, and operator training — and the GEI reduction is immediate upon deployment. For smelters with older potroom management systems (some Hindalco and BALCO lines date to the 1980s-90s), PFC abatement through feeder modernisation can deliver 0.5 to 1.5 tCO₂e/t GEI reduction at a cost well below the CCTS penalty value. This is the fastest-payback abatement lever for most legacy Indian smelters because the investment is operational rather than infrastructural.
Reducing the specific electricity consumption (SEC) of the smelting cells from a typical 14.5 MWh/t toward the best-practice target of 13.0 MWh/t cuts Scope 2 GEI proportionally. A 0.5 MWh/t SEC reduction on coal CPP power reduces GEI by approximately 0.43 tCO₂/t (at 0.85 tCO₂/MWh CPP factor). The most effective cell-level interventions include: upgrading to low-energy cell designs (AP40+ equivalent, SAMI technology); bath chemistry optimisation (alumina concentration, fluoride additions, metal pad height); modern amperage distribution systems; and cathode design improvements (TiB₂ coating). These are medium-term investments requiring potline rebuilds or remodelling during scheduled relining cycles. The 43 Mtpa of Indian blast furnaces due for relining before 2030 principle applies here too: aluminium potline remodelling happens at 6 to 10 year intervals. Smelters approaching a relining cycle should incorporate energy efficiency upgrades into the relining plan, with CCTS Phase 2 target trajectories influencing the design specification.
Scope 1 direct emissions from aluminium smelting arise from: anode carbon consumption (approximately 0.35–0.45 tCO₂/t Al from anode oxidation — unavoidable with carbon anodes); fuel combustion in alumina calciners, carbon bake furnaces, and auxiliary processes; and PFCs (addressed under lever 2). The anode consumption component is governed by the carbon anode quality and cell operational parameters. Higher anode reactivity (lower anode butts consumption) reduces CO₂ per tonne. Calciner efficiency improvements reduce fuel combustion GHG. Waste heat recovery from pot gas and hot metal casting provides thermal energy that offsets fuel consumption. These measures are valuable but relatively small in GEI impact compared to the electricity-dominated Scope 2 component — which, for coal-CPP-powered Indian smelters, accounts for approximately 70–80% of total GEI. The exception is if inert anode technology (Elysis-type) becomes commercially available post-2030, which would eliminate the 0.35–0.45 tCO₂/t from anode carbon oxidation entirely, but this technology is not yet deployable at scale in India.
The triple value of RE — why CCTS alone understates the investment case
For Indian aluminium smelters that export to the EU — and India exported significant aluminium to EU markets in 2022-23, with aluminium accounting for 27.18% of India’s CBAM-exposed EU goods — the financial case for renewable electricity procurement is not just the CCTS CCC revenue. It is the sum of three simultaneous regulatory value streams that are each individually positive and are jointly decisive.
0.9 tCO₂/MWh × Rs 800/CCC ÷ 1,000 kWh/MWh Rs 0.72/kWh
0.9 tCO₂/MWh × €65/tCO₂e × Rs 90/€ ÷ 1,000 kWh/MWh Rs 5.27/kWh
Physical RE satisfies RCO; avoids REC cost ~Rs 1.89/kWh Rs 1.89/kWh
Note: CCTS value based on Rs 800/CCC (analyst mid-range). CBAM value based on EU ETS price of €65/tCO₂e and Rs 90/€ exchange rate; coal CPP emission factor 0.9 tCO₂/MWh. RCO value based on current REC market price of approximately Rs 1,500–2,500/MWh (using midpoint Rs 1,890/MWh). This total value is compared against landed RE open access cost of Rs 4.30–5.50/kWh in Odisha and Chhattisgarh. Net economic gain: Rs 2.38–3.58/kWh before electricity cost savings from RE versus coal CPP. If RE is cheaper than coal CPP (which it is in these states by Rs 0.50–1.50/kWh), the net gain further increases. CBAM value is large because CBAM applies to BOTH Scope 1 and Scope 2 for aluminium — unlike for steel, where only Scope 1 is currently in scope.
The CBAM Scope 2 value component is the largest single element of this value stack and the one most often underweighted in Indian smelter treasury models. At the EU ETS price of €65/tCO₂e, every tonne of CO₂ eliminated from electricity embedded in aluminium exported to the EU eliminates €65 in CBAM certificate cost. For a smelter using 14 MWh/t of aluminium from coal CPP at 0.9 tCO₂/MWh, the full Scope 2 embedded emission is 12.6 tCO₂/t Al. Eliminating this through 100% RE procurement saves approximately €819 per tonne in CBAM certificates for Scope 2 — reducing total CBAM liability from approximately €1,000+ per tonne to approximately €100–200 per tonne from Scope 1 alone.
Vedanta has publicly signalled a 600 MW power purchase agreement for renewable electricity at Jharsuguda. At Jharsuguda’s specific electricity consumption of approximately 14 MWh/t and production of 1.24 Mt, total electricity demand is approximately 17.4 TWh per year. A 600 MW RE plant at approximately 25% capacity factor (CUF for solar in Odisha) generates approximately 1.31 TWh per year — covering approximately 7.5% of total power demand. At the coal CPP emission factor of 0.9 tCO₂/MWh, this substitution eliminates approximately 1.18 million tCO₂e per year from Vedanta’s GEI. Against Jharsuguda’s FY2026-27 target of 12.8259 tCO₂/t: baseline 13.4927, so 1.18 Mt CO₂ saved ÷ 1.238 Mt Al production = GEI reduction of approximately 0.95 tCO₂/t — more than the full 0.6668 tCO₂/t reduction required to meet the FY2026-27 target from baseline. A single 600 MW RE commitment, implemented effectively, takes Vedanta Jharsuguda from baseline to comfortably below its two-year target, generating approximately 0.3 tCO₂/t surplus = approximately 370,000 CCCs from this plant alone in FY2026-27.
The compliance calendar — what smelters need to do by when
BEE formally launched the CCTS compliance framework. All 13 primary aluminium smelters began digitally tracking GHG emissions for FY2025-26. GEI data must be collected at gate-to-gate boundary: direct fuel combustion (Scope 1), captive power plant emissions (Scope 2 — captive), grid electricity consumption (Scope 2 — market), and anode carbon oxidation (Scope 1 process). Smelters that have not established product-level GHG monitoring systems by now are already in compliance risk.
Monitoring and Verification Plans for the CCTS programme — specifying emission sources, measurement methodologies, data quality controls, and internal reporting procedures — were due for submission to BEE through the Indian Carbon Market portal. Smelters that delayed MRV plan finalisation face procedural risk that could complicate ACVA verification timelines.
Obligated entities are required to submit a five-year decarbonisation action plan and an annual activity plan for FY2025-26 through the ICM Portal. These plans should map the four abatement levers against target trajectories, specify capital commitments for RE procurement and efficiency investments, and demonstrate a credible pathway to CCTS Phase 2 alignment. The five-year plan matters because CCTS Phase 2 targets are expected from FY2027-28 — smelters must show BEE they have a viable pathway beyond Phase 1.
FY2025-26 GHG reports (Forms A, B, C, D, and E2) verified by Accredited Carbon Verification Agencies must be submitted. This is the deadline from which the 4-month post-year-end window runs — approximately July 31, 2026. Upon verified submission, BEE calculates each entity’s CCC surplus or deficit. Surplus entities await CCC issuance to their GRID-INDIA registry accounts. Deficit entities must purchase CCCs on the power exchange (IEX/PXIL/HPX, trading expected to begin mid-2026) or face Environmental Compensation at 2× the average trading price.
The NSCICM must gazette-notify Phase 2 GEI trajectories before April 2027. For aluminium, Phase 2 targets must tighten materially relative to Phase 1 if CCTS is to align India’s industrial GEI trajectory with the 2035 NDC pathway. For smelters still primarily on coal CPP power in 2027, Phase 2 will create far greater compliance cost pressure than Phase 1. The window to invest in RE procurement, PFC abatement, and potline efficiency upgrades is now — before Phase 2 makes inaction structurally expensive.
Frequently Asked Questions
Does purchasing RECs count toward reducing a smelter’s GEI under CCTS?
No. Purchasing Renewable Energy Certificates on the exchange satisfies the Renewable Purchase Obligation and Renewable Consumption Obligation, but does not reduce a smelter’s CCTS Scope 2 GEI. The gate-to-gate CCTS methodology counts the actual electricity consumed at the plant at the CEA grid emission factor — or at the CPP emission factor if the plant has captive power. A REC is a certificate that the renewable electricity was generated somewhere; it does not change the emission factor of the electricity the smelter actually consumed. Only physical renewable electricity — delivered to the potlines through captive generation, group captive, or green open access third-party procurement — reduces the Scope 2 GEI for CCTS purposes. Similarly, for CBAM, RECs are not recognised as reducing embedded Scope 2 emissions; only physical RE counts. This distinction is commercially critical: RECs at Rs 1,500–2,500/MWh satisfy the RCO but deliver none of the CCTS or CBAM value that physical RE delivers.
What happens if a smelter increases production during the compliance year?
CCTS targets are emission intensity targets — tCO₂e per tonne of equivalent product — not absolute caps. If production increases, the GEI target per tonne remains the same, but the absolute CCC surplus or deficit scales proportionally with production volume. A smelter that increases production by 10% while holding its GEI constant earns 10% more CCCs if it is already below its target, or faces 10% higher purchase costs if it is above its target. This is a key feature of India’s intensity-based ETS design: it does not penalise economic growth, only inefficient production. The CCC formula makes this explicit — both surplus issuance and deficit purchase are calculated as (GEI difference) × (actual production). Higher-volume years create higher financial stakes from GEI performance, making the investment case for abatement actions stronger as capacity expansions proceed.
What is the CBAM treatment of aluminium versus steel, and why does it matter for smelter strategy?
For aluminium exporters to the EU, CBAM covers both Scope 1 and Scope 2 embedded emissions — unlike for steel, where currently only Scope 1 is in scope. For aluminium, this means the 12–15 tCO₂/MWh of coal CPP-sourced electricity embedded per tonne of metal is directly reflected in CBAM certificate costs. At an EU ETS price of €65/tCO₂e and a coal CPP emission factor of 0.9 tCO₂/MWh for 14 MWh/t Al, full Scope 2 CBAM liability is approximately €819 per tonne of aluminium. Eliminating this through 100% renewable electricity reduces CBAM liability by this amount. This is why the triple value stack (CCTS + CBAM + RCO) for RE is so large for aluminium specifically: approximately Rs 7.88 per kWh of coal power replaced, against a landed cost of RE open access in Odisha or Chhattisgarh of approximately Rs 4.30–5.50 per kWh. The net regulatory value alone justifies the RE investment — before any electricity cost savings are considered.