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Power & Carbon Markets · RCO · Cross-Cutting⚠ FY2025-26 Energy Accounts Due 31 July 2026
India’s Renewable Consumption Obligation for Industrial Consumers: The 29.91% to 43.33% Trajectory, Rs 347/MWh Buyout, and the Unresolved Double-Counting Question That Determines Whether Captive Solar Delivers a Triple Return
India’s Renewable Consumption Obligation — notified by the Ministry of Power in September 2025 under the Energy Conservation (Amendment) Act 2022, 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 finalised the buyout price at Rs 347/MWh in February 2026 for FY2024-25 and FY2025-26, based on the weighted average REC trading price of Rs 346.74/MWh. Three compliance routes are non-hierarchical — direct RE consumption, REC purchase, or buyout — meaning entities can choose any combination at any time. BEE monitors compliance. FY2025-26 energy accounts are due July 31, 2026, and compliance reports after REC purchase or buyout payment are due December 31, 2026. Every industrial CCTS-covered entity is therefore simultaneously managing two compliance deadlines: Form A for CCTS by approximately July 31, 2026, and RCO energy accounts by the same date. The article’s central commercial question — whether the same MWh of captive solar can simultaneously satisfy the RCO and improve the CCTS Scope 2 GEI — has not been definitively resolved in the current regulatory framework. If it can, captive solar delivers a triple return that makes it the highest-return industrial decarbonisation investment available. This article maps the full RCO framework, builds the cost comparison between the three compliance routes, and analyses the double-counting question that industrial CFOs and compliance teams must resolve before July 2026.
The RCO framework under the September 2025 Ministry of Power notification is a fundamental expansion of India’s renewable energy compliance architecture. It moves the obligation from electricity distribution companies (discoms) — who bore the RPO burden under the Electricity Act 2003 — to designated consumers themselves: open access consumers, captive power plant users, and energy-intensive industrial entities. The four RCO sub-categories — wind (rising from 0.81% to 3.48% by FY2029-30), hydro (0.66% to 1.33%), distributed renewable energy or DRE (1.5% to 4.5%), and other renewables including solar (26.94% to 34.02%) — must be met independently for DRE but interchangeably for wind, hydro, and other renewables. This means an industrial entity can over-comply on solar and use the surplus to offset a shortfall on wind or hydro — but cannot use solar surplus to meet the DRE (rooftop and distributed) sub-target.
The three compliance routes are non-hierarchical and each has a different cost and carbon implications profile. Direct RE consumption — whether through captive solar or wind, open-access renewable procurement, or green tariff from discoms — provides the lowest compliance cost per MWh and simultaneously reduces the CCTS Scope 2 GEI. REC purchase — at approximately Rs 345-350/MWh based on recent exchange clearing prices — satisfies RCO but does not change the CCTS Scope 2 GEI because the physical electricity consumed is still grid power at the 0.710 tCO₂/MWh grid emission factor. Buyout payment — at Rs 347/MWh as fixed by CERC in February 2026, with 5% annual escalation from FY2026-27 — is the most expensive route and provides zero carbon benefit. For industrial entities that are simultaneously CCTS-obligated, the compliance route choice is not just a cost decision — it is a GEI decision that affects CCC issuance and CBAM embedded emission calculation.
The aluminium smelter partial exclusion is commercially significant. The September 2025 RCO notification explicitly excludes 50% of fossil-fuel-based electricity consumed in aluminium smelters from the RCO calculation. This means an aluminium smelter consuming 5,000 GWh per year of coal CPP electricity calculates its RCO obligation on only 2,500 GWh of that consumption — halving the absolute MWh of renewable energy required for compliance. This exclusion was designed to prevent the RCO from imposing an unmanageable compliance burden on primary aluminium producers operating large captive coal power plants while the RE transition for their scale of consumption is still underway. The exclusion does not apply to CCTS GEI calculations — the full Scope 2 consumption from coal CPP is included in the CCTS GEI boundary. This asymmetry means aluminium producers calculate their RCO obligation on half their coal CPP consumption but their CCTS GEI on all of it.
The double-counting question between RCO and CCTS is the most commercially important unresolved regulatory issue in India’s decarbonisation framework. The question: can the same MWh of captive solar that satisfies the RCO (as renewable consumption) also reduce the CCTS Scope 2 GEI (by reducing tCO₂e per unit of output)? The RCO notification does not address this question. The CCTS Detailed Procedure does not address this question. Based on regulatory logic, the answer is likely yes — because the RCO and CCTS measure different things (percentage of renewable consumption versus emission intensity per unit of output) and use different metrics. But BEE has not published a definitive guidance note on this point. Until it does, industrial entities face regulatory uncertainty on the triple-return value proposition of captive solar. The safest approach — and the one recommended by the limited industry guidance available — is to separately track and document the REC-equivalent of captive solar consumption for RCO purposes and the emission factor impact for CCTS Scope 2 purposes, maintaining distinct data trails for each compliance obligation.
Group-level aggregation is permitted for entities under common control. The RCO notification allows holding companies and cooperative societies to aggregate their RCO compliance across all designated consumer subsidiaries. A corporate group where one subsidiary (say, an aluminium smelter in Odisha) has significant captive solar and over-complies on RCO can use that surplus against a shortfall at another group entity (say, a steel plant in Gujarat). This aggregation provision is commercially significant for diversified industrial groups — Tata, Hindalco, JSW, Vedanta — that operate multiple designated consumer entities across different states with different renewable resource access. The group compliance officer should be managing RCO compliance at the holding company level, not at the individual plant level.
The RCO trajectory — year-by-year targets through FY2029-30
The September 2025 notification sets six years of annual RCO targets, providing industrial planners with a clear compliance trajectory for capital allocation decisions. The overall RCO rises from 29.91% in FY2024-25 to 43.33% by FY2029-30 — a 13.42 percentage point increase in five years, requiring approximately 2.7 percentage points of additional renewable consumption per year. Within the total, the four sub-targets move at different rates.
The DRE (distributed renewable energy) sub-target — covering rooftop solar, small-scale distributed generation, and behind-the-meter RE — grows from 1.5% in FY2024-25 to 4.5% by FY2029-30 and must be met independently. For an industrial consumer with 1,000 MWh per day of electricity consumption, the FY2025-26 DRE sub-target of 2.0% = 20 MWh per day from distributed renewable sources. This cannot be substituted by large open-access solar or wind farms — it specifically requires distributed, on-site or near-site small-scale RE. Most large industrial plants have limited rooftop area for the DRE requirement at this scale, making the DRE sub-target the most practically challenging component for large manufacturing facilities.
The three compliance routes — cost and carbon comparison
Captive solar or wind (Rs 2.5-3.5/kWh capex + opex all-in) versus grid power at Rs 5-8/kWh. Open-access solar at Rs 3.5-4.5/kWh. Green tariff from discom (if available): Rs 4-5/kWh. Direct RE simultaneously satisfies RCO and reduces CCTS Scope 2 GEI — the electricity consumed has near-zero emission factor. Also reduces CBAM embedded emissions on EU exports. The triple-return route — lowest long-term cost and highest regulatory return.
RECs traded on IEX, PXIL, HPX at approximately Rs 345-350/MWh. Satisfies RCO by attributing renewable generation to your consumption. Does NOT reduce CCTS Scope 2 GEI — the physical electricity you consume remains grid power at 0.710 tCO₂/MWh. The REC is a certificate, not physical RE. Does not reduce CBAM embedded emissions. Use RECs for RCO compliance only when captive RE or open access is unavailable. CERC 2026 amendment added VPPAs (Virtual Power Purchase Agreements) as an eligible REC generation route.
Cash payment to state renewable development fund. 75% of buyout funds go to state RE development. 5% annual escalation: FY2026-27 = ~Rs 364/MWh; FY2027-28 = ~Rs 382/MWh; FY2028-29 = ~Rs 401/MWh; FY2029-30 = ~Rs 421/MWh. Zero carbon benefit — no CCTS GEI improvement, no CBAM reduction. Pure cost with no asset creation. CERC confirmed it is non-hierarchical — entities can choose buyout without exhausting RE or REC routes first. Appropriate only when RE procurement or REC purchase is temporarily unavailable or impractical.
The cost of RCO compliance — what it means for a 1,000 MW industrial consumer
The calculation makes the captive solar investment case clear: the buyout route costs Rs 100 crore per year with zero asset creation and zero carbon benefit. The captive solar route costs Rs 2,500 crore once (plus maintenance) but generates Rs 282-312 crore per year in combined returns from electricity cost saving, CCTS CCC value, and CBAM Scope 2 reduction — a payback period of approximately 8-9 years on an unlevered basis, which improves to 5-6 years with green finance at preferential rates from taxonomy-aligned lenders. The buyout route is not a compliance strategy — it is a transitional option while captive RE is being planned and commissioned. Any industrial entity paying the RCO buyout for more than two consecutive years is effectively subsidising state renewable development at its own cost while forgoing the CCTS, CBAM, and energy cost returns from direct RE investment.
The double-counting question — does captive solar satisfy both RCO and CCTS simultaneously?
This is the regulatory question that no published guidance has definitively answered, and the one that has the largest commercial consequence for industrial decarbonisation capital allocation decisions. The question has two parts.
Part 1 — RCO and CCTS GEI: Can the same MWh of captive solar electricity consumption satisfy the RCO (by counting as renewable consumption toward the 33.01% target) AND simultaneously reduce the CCTS Scope 2 GEI (by applying a near-zero emission factor to that electricity in the GHG calculation)? The regulatory logic suggests yes — because RCO measures the percentage of renewable electricity consumed, while CCTS measures the emission factor of electricity consumed in calculating GEI. These are different metrics measured against different baselines. The same MWh can satisfy both because it is simultaneously a unit of renewable consumption (RCO) and a unit of low-carbon electricity in the GEI calculation (CCTS). This interpretation is supported by the fact that the CCTS Detailed Procedure explicitly includes Scope 2 emission factors from purchased electricity in the GEI calculation — and captive solar has a near-zero emission factor by definition.
Part 2 — REC and CCTS GEI: Can a purchased REC (used for RCO compliance) also be used to reduce the CCTS Scope 2 GEI? Here the answer is almost certainly no — because the REC represents the renewable attribute of electricity that was generated elsewhere and consumed by someone else. The industrial entity that buys the REC does not consume renewable electricity; it consumes grid electricity at the standard 0.710 tCO₂/MWh emission factor. The REC gives it renewable attribute credit for RCO purposes but does not change the physical electricity it consumes or its Scope 2 emission intensity.
BEE has not published a definitive guidance note on the RCO-CCTS interaction as of April 2026. Given both Form A (CCTS) and energy accounts (RCO) are due by approximately July 31, 2026, industrial entities cannot wait for this clarification before completing their compliance data collection. The recommended approach for compliance teams: (1) Document captive solar consumption separately from grid consumption in both the RCO energy accounts and the CCTS monitoring data. (2) Apply a near-zero emission factor to captive solar in the CCTS Scope 2 calculation, consistent with the BEE Detailed Procedure’s treatment of renewable electricity. (3) Record captive solar generation as satisfying RCO renewable consumption in the energy accounts. (4) Maintain separate data trails for each obligation — do not conflate the RCO REC-equivalent of captive solar with CCTS CCC issuance calculations. (5) Explicitly flag the dual-use of captive solar in both the RCO compliance report and the ACVA verification report for CCTS, requesting the ACVA to confirm the treatment. If BEE subsequently clarifies that captive solar cannot simultaneously satisfy both obligations, entities that have maintained separate documentation will be best positioned to restructure their compliance approach with minimum disruption.
Compliance timeline — what is due and when
FY2024-25 energy accounts due. Certified by designated plant head. Energy accounts must document total electricity consumption and renewable consumption (captive, open access, green tariff, REC) for the full financial year. Entities that missed this deadline are in default under Section 26(3) of the Energy Conservation Act 2001. Penalties may be levied by BEE or State Designated Agencies.
FY2024-25 RCO compliance report due — after making good any shortfalls through REC purchase or buyout payment. Entities that had a shortfall (consumed less than 29.91% renewable in FY2024-25) must have purchased RECs or paid the Rs 347/MWh buyout by this date and submitted the compliance report. Missing this deadline means the shortfall is unresolved and subject to penalty.
FY2025-26 energy accounts due — same date as CCTS Form A deadline. Certified by designated plant head AND independently verified by a BEE-accredited energy auditor. Energy auditor verification adds 4-6 weeks to preparation timeline. Entities should engage a BEE-accredited energy auditor by mid-May to ensure July 31 delivery. Note: this is the same window as CCTS Form A + ACVA verification — compliance teams are managing both obligations simultaneously.
FY2025-26 RCO compliance report due — after making good any shortfall in FY2025-26 RCO target (33.01%) through REC purchase or buyout payment at Rs 347/MWh. Entities should resolve their shortfall through the lowest-cost route available — REC purchase at Rs 345-350/MWh or RE procurement — before reverting to the buyout option.
Frequently Asked Questions
What is India’s RCO and who does it apply to?
The Renewable Consumption Obligation is a mandatory requirement under the Energy Conservation (Amendment) Act 2022, notified by the Ministry of Power in September 2025. It applies to all designated consumers — electricity distribution licensees, open-access consumers, and captive power plant users. For industrial entities, it covers energy-intensive industries including steel, aluminium, fertilisers, cement, chlor-alkali, and others. The RCO requires these entities to source a specified percentage of their total electricity consumption from renewable sources, rising from 29.91% in FY2024-25 to 43.33% by FY2029-30. Compliance can be achieved through direct RE consumption, REC purchase, or buyout payment at Rs 347/MWh (with 5% annual escalation from FY2026-27). BEE monitors compliance. Group-level aggregation is permitted for entities under common control at the holding company level.
What is the RCO buyout price and how was it calculated?
CERC finalised the RCO buyout price at Rs 347/MWh for FY2024-25 and FY2025-26 through a suo-motu order in February 2026. The price was calculated based on the weighted average REC trading price of Rs 346.74/MWh from December 2024 to November 2025, covering transactions on IEX, PXIL, and Hindustan Power Exchange as well as bilateral trades through licensed power traders. The price was rounded to Rs 347/MWh. From FY2026-27 onwards, the buyout price escalates at 5% per year. CERC confirmed that the three compliance routes — direct RE, REC purchase, and buyout — are non-hierarchical: entities can choose any route without needing to exhaust the other options first. 75% of buyout funds are allocated to state renewable energy development funds.
Can the same captive solar installation satisfy both the RCO and improve the CCTS Scope 2 GEI?
The regulatory framework suggests yes — but BEE has not published a definitive guidance note as of April 2026. The RCO and CCTS measure different things: RCO measures the percentage of renewable electricity consumed, while CCTS measures emission intensity per unit of production output. Captive solar simultaneously satisfies the RCO (as renewable consumption) and reduces the CCTS Scope 2 GEI (by applying a near-zero emission factor to that electricity in the GHG calculation). A purchased REC, by contrast, satisfies the RCO but does not change the Scope 2 GEI because the physical electricity consumed remains grid power at 0.710 tCO₂/MWh. Until BEE issues guidance, compliance teams should maintain separate documentation for each obligation and have their ACVA explicitly confirm the dual-use treatment in the CCTS verification report.