Carbon Credits and Decarbonization for India's Aluminium Sector in 2026: CCTS Targets Meet CBAM Costs
India is the world's second-largest producer of primary aluminium, and by some distance the most carbon-exposed thing the country exports. A tonne of Indian aluminium carries roughly 20 to 21 tonnes of CO₂ equivalent, against a global average nearer 15 and closer to four for smelters running on Norwegian or Canadian hydropower. The reason is not chemistry. It is the captive coal power feeding Indian potlines.
That gap was an abstraction until 2026. This year it became a line item twice over — once at home, where aluminium sits in the first tranche of India's Carbon Credit Trading Scheme with legally binding intensity targets, and once in Europe, where the CBAM definitive regime began charging on 1 January. The trade data already shows it: India's unwrought aluminium exports to the EU fell from about 18,650 tonnes in the year to January 2025 to roughly 10,875 tonnes a year later, a decline of nearly 42%.
Here is what the two regimes actually require, which abatement levers move the number, and where carbon credits legitimately fit.
Aluminium's carbon problem is an electricity problem
Smelting aluminium through the Hall-Héroult process consumes on the order of 13,000 to 15,000 kWh per tonne of metal. In India, the overwhelming majority of that power comes from captive coal plants sitting next to the smelter. The consequence is that roughly four-fifths of the sector's footprint is indirect — Scope 2 and captive generation — rather than process emissions.
That is unusually good news, and it is worth being explicit about why. Cement's calcination emissions and steel's coking coal are chemically embedded in the product; removing them requires new process technology. Aluminium's emissions are mostly a procurement problem, and power contracts can be renegotiated in a way that clinker chemistry cannot. The sector accounts for roughly 83 MtCO₂e, close to 2.8% of India's greenhouse gas emissions — most of it addressable with decisions a CFO can sign.
This makes aluminium a genuinely different problem from the one we set out for cement and steel companies in India, where abatement runs into hard technological limits well before it runs into budget limits.
What CCTS actually requires from aluminium producers
Aluminium was notified in the first tranche of CCTS obligated sectors in October 2025. A second tranche in January 2026 added 208 more entities, bringing the scheme to roughly 490 obligated units across nine sectors. Primary aluminium alone accounts for about 16% of the baseline emissions covered by the scheme — the largest single share of any sector in India's compliance carbon market.
The mechanics, in short:
Baseline year: FY 2023-24 verified emissions intensity.
Target years: FY 2025-26 and FY 2026-27, with legally binding greenhouse gas emission intensity (GEI) targets.
Reduction range: approximately 2.8% to 7.06% across the compliance period, set installation by installation rather than as a single sector number.
Unit of account: tCO₂e per tonne of product. CCTS is an intensity scheme, not an absolute cap — growing output does not by itself put you out of compliance.
Settlement: beat your target and you are issued surplus Carbon Credit Certificates; miss it and you buy CCCs or pay environmental compensation.
The first compliance filing fell due on 31 July 2026, and first trading of Carbon Credit Certificates on the regulated power exchanges is expected from around October 2026. We covered the filing mechanics, penalties and verification requirements in detail in our note on India's first CCTS compliance deadline.
One strategic caution. Several analysts expect the first compliance cycles to be structurally long — targets were set conservatively, banking is permitted, and verification capacity is still maturing. A market with more certificates than it needs discovers a low price. Treat any CCC revenue as upside, not as the return that justifies an abatement investment.
Aluminium is the rare Indian sector where two regulators are measuring the same tonne of carbon for different purposes — and the one that prices it highest sits outside India.
CBAM is already showing up in order books
The EU's Carbon Border Adjustment Mechanism left its reporting-only phase on 1 January 2026. The dates that matter to an Indian exporter and its EU customers now look like this:
31 March 2026 — authorised CBAM declarant status became mandatory for EU importers bringing in more than 50 tonnes of covered goods a year.
7 April 2026 — the first quarterly CBAM certificate price was set at €75.36 per tonne of CO₂e, benchmarked to EU ETS auction prices.
February 2027 — certificate sales begin, covering 2026 emissions liabilities.
30 September 2027 — the first annual CBAM declaration falls due, covering calendar year 2026 imports.
Penalty — €100 per tonne for insufficient surrender, indexed to European inflation.
The commercial damage is not really the certificate price — it is the default-value penalty. An exporter who cannot supply verified installation-level data hands its EU customer a set of EU default values instead, and those defaults carry a deliberate markup of 10% in 2026, rising to 20% in 2027 and 30% from 2028. For Indian aluminium, defaults can sit 30% to 80% above actual verified emissions. CEEW has estimated the effective carbon cost at 12% to 22% of export value, and Indian exporters have reportedly been discounting by 15% to 22% to keep EU buyers.
Two consequences follow. First, verified installation-level data is the highest-return compliance spend available to an Indian aluminium producer right now — it is cheaper than the discount you are currently absorbing. Second, scrap is a strategic asset: aluminium scrap under CN code 7602 sits outside CBAM scope entirely, and secondary metal produced from post-consumer scrap is effectively zero-rated for embedded emissions. Our 2026 CBAM guide for Indian exporters walks through the declarant relationship and the data your EU customer will ask you for.
The abatement levers that actually move the number
Ranked by tonnes of CO₂ removed per rupee spent, and by whether they can realistically land inside the FY 2026-27 target window:
Renewable and round-the-clock hybrid power. The only lever large enough to change the headline number. Vedanta Aluminium has committed to 1,500 MW of renewable capacity by 2030 through long-term PPAs and has reported an 8.96% fall in GHG intensity. Storage-backed RTC contracts matter more than nameplate capacity, because a potline cannot follow a solar curve.
Biomass in alumina refining. Refining heat is easier to switch than smelting power. Hindalco's Belagavi refinery runs biomass-fired boilers supplying roughly a third of its steam demand — a proven, permittable template.
Potline efficiency and PFC control. Amperage optimisation, anode effect frequency reduction and waste-heat recovery. Perfluorocarbons from anode effects have global warming potentials in the thousands, which makes their suppression one of the cheapest tonnes available anywhere in the plant.
Secondary and recycled content. Remelting scrap uses on the order of 5% of the energy of primary production, and carries a CBAM advantage that primary metal cannot buy its way to.
Longer-horizon technology. Inert anodes, hydrogen calcination and CCUS on captive power are 2030s levers. Budget for them in capex planning; do not count them towards an FY 2026-27 intensity target.
Where carbon credits legitimately fit — and where they do not
Three different instruments are in play and conflating them is the most common and most expensive mistake we see:
Carbon Credit Certificates (compliance, domestic). Earned by beating your CCTS target or bought on the power exchanges to close a shortfall. Group entities outside the obligated list can also generate them — see how the CCTS offset mechanism works for non-obligated companies.
CBAM (no offsetting). You cannot retire voluntary carbon credits against a CBAM liability. Only a carbon price genuinely paid in the country of production is deductible, and CCTS is not yet recognised for that purpose. The only route is lower verified embedded emissions.
Voluntary credits (VCM). Appropriate for residual Scope 1 and Scope 3, for customer-facing neutrality claims, and for meeting brand-driven supply chain asks. Quality is now the whole game — buy against the ICVCM Core Carbon Principles label or an equivalent standard, not on price alone.
The order of operations does not change: measure at installation level, reduce with power contracts and process discipline, then use credits for the genuinely hard residual. Credits bought before the measurement work is done tend to be both expensive and unusable for the disclosure that prompted the purchase.
Where Csquare fits
Csquare works with Indian manufacturers on precisely this stack: installation-level GHG inventories and MRV built once and used twice, robust enough for accredited verification under CCTS and for an EU verifier reviewing CBAM embedded emissions; CCTS target modelling and CCC position planning, so you know before the compliance window whether you are long or short; BRSR and ESG reporting that reconciles to the same numbers; and sourcing of verified, high-integrity carbon credits for the emissions you cannot yet engineer out.
If your smelter, refinery or downstream unit is inside CCTS, ships to the European Union, or both, get in touch with the Csquare team and we will map your exposure across both regimes.
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