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Process emissions from the chemical breakdown of limestone account for nearly 60 percent of a cement plant’s carbon footprint. As India rolls out its Carbon Credit Trading Scheme, understanding how regulatory baselines accommodate this unavoidable calcination penalty is critical for the sector’s long term survival and the eventual necessity of carbon capture.
The Calcination Penalty: How India’s CCTS Treats Unavoidable Process Emissions in Cement Read More »
PM e-DRIVE subsidises the purchase price of electric heavy trucks, but fleet operators make decisions on total cost of ownership over a vehicle’s life. At Rs 87.67/litre diesel and Rs 8–12/unit for commercial EV charging, the TCO crossover for heavy electric trucks sits at 250,000–400,000 km of cumulative annual operation. For captive industrial fleets at steel plants, aluminium smelters, and cement complexes, which routinely log 150,000–300,000 km/vehicle/year, the numbers are approaching parity faster than the market expects.
BRSR Core became mandatory for India’s top 150 listed companies by market cap from FY2023-24 and for the top 1,000 from FY2024-25. It requires reasonable assurance on nine Key Performance Indicators including verified Scope 1 and Scope 2 GHG emissions, energy intensity, water intensity, and selected Scope 3 emissions. For industrial companies also under CCTS, the two frameworks produce essentially the same GHG data — but with different verification standards and different penalties for non-compliance. This article maps the overlap, the divergences, and the dual-framework compliance strategy.
India imports approximately 80 million tonnes of coking coal per year — 100% of its metallurgical coal requirement — from Australia, the USA, Canada, and Mozambique. The West Asia War added 30–40% freight premium to delivered coking coal costs as shipping rerouted from Suez/Red Sea to the Cape of Good Hope. At Rs 20,000/t delivered coking coal, this feedstock alone represents approximately Rs 56,000 per tonne of BF-BOF steel produced. DRI-EAF with natural gas eliminates this entirely — replacing coking coal with a fuel that has alternatives, domestic production potential, and no Suez exposure.
India’s Perform Achieve and Trade scheme has been the mandatory energy efficiency compliance mechanism for Designated Consumers since 2012. The CCTS replaces it as the primary carbon and energy performance instrument from FY2025-26. This analysis maps what changes, what stays the same, what happens to accumulated ESCerts, and how the dual-period transition of 2025-2027 must be managed by entities that were PAT obligated in Cycle 2 and Cycle 3.
India’s Climate Finance Taxonomy released in draft in May 2025 and under consultation defines which economic activities and assets qualify for green and transition finance labelling in India. For CFOs at steel, aluminium, and fertiliser companies, the taxonomy determines access to sovereign green bond proceeds, sustainability-linked lending terms, and eventual alignment with the global sustainable finance architecture. The draft thresholds are more demanding than many industry participants anticipated. This analysis maps exactly which production routes qualify, which are excluded, and what asset-level actions enable taxonomy eligibility.
The leaked EU CBAM provisional benchmark published in December 2025 contains the single most commercially important number for India’s aluminium industry: the secondary aluminium CBAM benchmark is 0.139 tCO₂e per tonne — versus 1.464 tCO₂e per tonne for primary aluminium. When more than 50% of aluminium is sourced from scrap, the secondary production route applies. India’s secondary aluminium industry, which produces at approximately 0.3-1.3 tCO₂/t depending on the energy source used for remelting, sits well below both the secondary benchmark and the primary benchmark. At EU ETS prices of approximately €60/tCO₂e, this means an Indian secondary aluminium exporter to the EU pays approximately €8/t in CBAM certificates while an Indian primary coal-CPP aluminium producer paying the default rate faces certificates at approximately €800/t. The CBAM gap between primary and secondary aluminium is the largest carbon cost differential in any CBAM-covered product category. This article maps India’s secondary aluminium sector — production volumes, scrap supply dynamics, energy consumption advantage, CCTS targets (finally gazette-notified on January 16, 2026), and the investment case for scaling secondary production as the CBAM advantage crystallises commercially from the first annual declaration in May 2027.
The Union Cabinet approved India’s updated Nationally Determined Contribution for 2031-2035 on March 25, 2026 — committing to a 47% reduction in emissions intensity of GDP from 2005 levels by 2035, a 60% non-fossil installed capacity share, and a carbon sink of 3.5-4 billion tCO₂e. India has already achieved 52.57% non-fossil capacity as of February 2026, meaning the power sector target is effectively achieved nine years early. The emissions intensity target — now 47% from 2005 levels versus 36% already achieved through 2020 — requires approximately 11 percentage points of further GDP intensity reduction over 2020-2035, or roughly 0.73 percentage points per year. But here is the industrial-sector contradiction that the 2035 NDC must resolve: while power sector emissions fell 3.8% in 2025, steel emissions rose 8% and cement emissions rose 10%. The industrial sector is moving in the wrong direction at exactly the moment the NDC announces a higher ambition. This article translates the 47% NDC target into sector-by-sector industrial language: what the required GDP intensity trajectory implies for CCTS GEI target-setting through Phases 3 and 4, how the 60% non-fossil capacity target interacts with industrial Scope 2 emissions, what the Carbon Brief analysis reveals about the contradiction between economic growth and intensity-based targets, and what the NITI Aayog $8 trillion investment requirement means for industrial green finance through 2035.
