Power & Carbon Markets

India added 6.1 GW of wind capacity in FY26, a 46% acceleration over FY25 and the highest annual addition in the sector’s history. Cumulative installed wind now exceeds 56 GW, with 28 GW under implementation. This is not only a renewable energy milestone. It is a carbon market event. Wind generation displaces coal at the margin, lowers India’s Grid Emission Factor, reduces CCTS Scope 2 GEI for every industrial consumer on the grid, and adds to the CCC supply pool that will determine Phase 1 carbon market price formation. This article traces the full chain from turbine to carbon credit price.

India’s Renewable Consumption Obligation — notified by the Ministry of Power in September 2025, superseding the 2023 framework — imposes mandatory year-wise renewable energy consumption targets on all designated consumers, rising from 29.91% of total electricity consumption in FY2024-25 to 43.33% by FY2029-30. CERC fixed the buyout price at Rs 347/MWh in February 2026, based on the weighted average REC price of Rs 346.74/MWh. Three compliance routes are non-hierarchical: direct RE consumption, REC purchase, or buyout payment. Aluminium smelters receive a partial exclusion: 50% of fossil-fuel-based electricity consumed is excluded from the RCO calculation. BEE monitors compliance. FY2024-25 shortfall resolution reports were due March 31, 2026. FY2025-26 energy accounts are due July 31, 2026. The article’s central commercially important question — and the one that no published guidance has definitively answered — is whether the same MWh of captive solar can simultaneously satisfy the RCO (as renewable consumption) and improve the CCTS Scope 2 GEI (reducing tCO₂e per unit of output). If it can: captive solar delivers a triple return — RCO compliance, CCTS GEI improvement, and CBAM Scope 2 reduction — making it the single highest-return industrial investment available. If it cannot: the industrial consumer must choose how to allocate its renewable energy between the two regulatory frameworks. This article maps the full RCO framework, builds the cost comparison between the three compliance routes, and analyses the double-counting question that BEE has not yet definitively resolved.

CBAM Article 9 of Regulation (EU) 2023/956 permits EU importers to reduce CBAM certificate obligations by the carbon price already paid in the country of production. Under the EU-India Strategic Agenda adopted September 2025, the EU committed to deducting carbon prices effectively paid in India — specifically the CCTS — from CBAM financial adjustments. The EU Commission’s December 2025 review acknowledged that carbon prices paid under different compliance schemes can be deducted. However, whether India’s CCTS qualifies remains contested: the CCTS is an intensity-based system generating credits for outperformance against a GEI target, while CBAM is designed to mirror the EU ETS which imposes absolute caps. The implementing act governing third-country carbon price recognition — expected in 2026-2027 — will determine whether Indian exporters can claim the deduction. If recognised at Rs 800/CCC (mid-range CCTS price), a BAT-upgraded steel plant at 2.0 tCO₂/t exporting to the EU would reduce its CBAM cost from Rs 2,898/t to approximately Rs 1,404/t. On 500,000 tonnes of EU exports that is Rs 747 crore per year in avoided CBAM cost — the largest single regulatory financial benefit available to any Indian steel exporter today. This article maps the legal mechanism, the incompatibility problem, the deduction value, and what Indian exporters must do right now to be positioned to claim it.

India’s Renewable Consumption Obligation replaced the RPO regime in 2024, creating binding RE consumption targets for all designated consumers — including aluminium smelters, steel mills, fertiliser plants, cement companies, and railways operating captive power plants or open access arrangements. The target trajectory runs from 29.91% of total electricity consumption in FY2024-25 to 43.33% by FY2029-30. Three compliance pathways exist: direct RE consumption, REC purchase, or buyout at CERC-determined price. CERC revised the buyout price upward to Rs 347/MWh for FY2024-25 after stakeholder consultation. For an aluminium smelter consuming 3,000 MU per year from coal CPP, the RCO shortfall in FY2024-25 represents 897 MU of RE that must be sourced — a REC compliance cost of approximately Rs 305 crore per year if met entirely through REC purchase. The same obligation cost only Rs 134 crore per year through incremental open-access captive solar procurement — and the same solar investment simultaneously generates CCTS Scope 2 GEI reduction, CBAM Scope 2 certificate savings, and RCO compliance credit. This article maps the full RCO compliance arithmetic, explains how RCO interacts with CCTS and CBAM, and builds the comparison between the three compliance routes for a typical heavy industrial consumer.