BRSR for Power + Utilities — Generation Mix, CEA Factors, CCTS Compliance, REC Strategy

Why this industry matters for BRSR

The Indian power + utilities sector accounts for ~40% of national CO₂ emissions + is the single largest emitting sector in the country. Within the SEBI BRSR Top 1,000 universe, the cohort includes:

• Central + state-owned generation companies (gencos): NTPC, NHPC, SJVN, THDC, NLC India, state-owned thermal + hydro generators
• Private IPPs (Independent Power Producers): Adani Power, Tata Power, JSW Energy, Reliance Power, Torrent Power, ReNew, Greenko (renewables-focused)
• Transmission: Power Grid Corporation (national), state transcos
• Distribution: Tata Power-DDL, BSES Rajdhani / Yamuna, Torrent Power discom businesses
• Renewables-only IPPs: Adani Green, ReNew, Tata Power Renewables, Suzlon, Inox Wind

The sector is unique in BRSR practice because it is the largest single Scope 2 emission supplier to every other sector (via grid electricity), AND a CCTS notified obligated sector with statutory decarbonisation targets, AND subject to Electricity Act / CERC regulation that drives ESG disclosures parallel to BRSR.

Material BRSR Core attributes

For a thermal genco, all 9 BRSR Core attributes are material, but 5 attributes dominate the assurance scope in practice:

Core attribute	Why material for power
GHG Emission Intensity per Revenue	Dominant emission contributor; intensity per MWh generated is the operational KPI (Scope 1 dominates)
Energy Footprint Disclosure	Fuel mix (coal, gas, oil, biomass) + thermal efficiency; energy intensity per unit generation
Water Withdrawal Intensity	Once-through cooling water + closed-loop cooling tower make-up; very high water intensity for thermal plants
Embracing Circularity — Waste	Coal ash (fly ash + bottom ash), gypsum from FGD, hazardous waste from boiler + turbine maintenance
Safety Metrics — LTIFR + Fatalities	High-voltage + boiler + height + confined-space work; contractor worker LTIFR typically 2-4× employee LTIFR

For renewable IPPs, the Scope 1 + water intensity are dramatically lower; energy footprint becomes about auxiliary consumption, waste centres on panel / blade end-of-life, safety on height + electrical work during installation + maintenance.

Generation-mix-driven Scope 1

Per-MWh emission intensity varies dramatically by fuel:

Generation type	Typical Scope 1 (tCO₂e per MWh)
Subcritical coal (older units)	0.95 - 1.10
Supercritical coal	0.85 - 0.95
Ultra-supercritical coal	0.75 - 0.85
Natural gas combined cycle	0.35 - 0.45
Natural gas open cycle	0.55 - 0.65
Diesel (peaking)	0.65 - 0.75
Biomass (with bagasse / agricultural residue)	0.05 - 0.15 (net of biogenic CO₂)
Hydro (large reservoir)	0.005 - 0.020 (mainly biogenic; site-specific)
Hydro (run-of-river)	0.001 - 0.005
Solar PV	0 (operational Scope 1)
Wind	0 (operational Scope 1)
Nuclear	0 (operational Scope 1; significant Scope 3 from fuel cycle)

The portfolio-weighted average intensity per MWh is a key disclosure under BRSR Principle 6. A genco with a high-coal portfolio reports higher absolute Scope 1 + higher per-MWh intensity; the strategic narrative covers fuel-mix transition (capacity additions in renewables / battery storage; coal-to-gas conversions; retirement of subcritical units).

Process emissions vs combustion emissions

Unlike cement, power generation has no significant process emissions. The entire Scope 1 is combustion-based + (for transmission) SF₆ leakage. Decarbonisation levers are therefore:

• Fuel mix transition (coal → gas → renewables → storage)
• Thermal efficiency improvement (supercritical → ultra-supercritical → super-critical with CCUS-readiness)
• Co-firing with biomass (5-10% biomass-coal blend is operationally feasible without major plant modification)
• CCUS (Carbon Capture, Utilisation, Storage) — pilot stage at NTPC Vindhyachal + similar; not yet commercially deployed at scale in India
• Blue + green hydrogen blending in gas turbines (early R&D)

CEA Grid Emission Factor application

The CEA CO₂ Baseline Database (currently V21, published 2025) is the canonical reference for grid emission factors in India. Key points for power-sector BRSR application:

• The CEA factor applies to electricity PURCHASED from the grid + consumed. It does NOT apply to the genco’s own Scope 1 (which uses fuel-input × IPCC emission factor methodology).
• For a thermal genco, internal electricity consumption (offices, control room auxiliary loads) typically uses the state grid factor for Scope 2.
• For a discom, the operational fleet + office consumption uses the state grid factor for Scope 2.
• Auxiliary consumption at the genco’s own plant — usually sourced from the genco’s own generation — is netted from the generation output (auxiliary % = aux consumed / gross generated). Net generation is the basis for sale + the per-MWh intensity calculation.

V21 (2025) reflects the FY 2023-24 generation mix at the all-India + state + regional levels. The annual V22 release is expected Aug-Oct 2026 reflecting FY 2024-25 mix.

CCTS thermal-power compliance

Thermal power is a CCTS 2023 notified obligated sector with sector-specific emission-intensity targets. Per the Ministry of Power’s CCTS notification + subsequent BEE sectoral target announcements:

• Target metric: tCO₂e per MWh of net generation at the unit level
• Cycle length: 3 years
• Over-achievers generate Carbon Credit Certificates (CCCs) tradable on IEX + PXIL
• Under-achievers buy + surrender CCCs OR pay environmental compensation per tonne of shortfall

For BRSR disclosure, the CCTS target + baseline + actual achievement + CCC activity for the current cycle should be narrated under Principle 6. The CCC purchase / sale activity affects the entity’s effective per-MWh emission intensity but does not change the BRSR Core attribute calculation (which is based on actual physical emissions, not net of CCC activity).

For the broader CCTS framework, see the CCTS glossary entry + the predecessor PAT Scheme (thermal power was a PAT obligated sector since 2012).

RPO + REC mechanics

Renewable Purchase Obligation (RPO) is a separate compliance regime under the Electricity Act 2003 + state ERC regulations:

• Obligated entities: distribution licensees + open-access consumers + captive consumers (gencos selling to obligated entities are indirectly obligated via the offtake contract)
• RPO trajectory: notified by Ministry of Power; escalating % of total electricity sourced from renewable sources. Recent trajectory targets ~43% renewable share by 2030.
• Compliance: can be met by direct renewable PPA, captive renewable generation, OR retirement of Renewable Energy Certificates (RECs) purchased on IEX / PXIL
• REC mechanism: the renewable generator separates the energy attribute (the underlying MWh) from the renewable attribute (the REC). The energy is sold to the grid at the conventional power tariff; the REC is sold separately to obligated entities.

For BRSR Principle 6 disclosure:

• RPO compliance % + REC retirement (in MWh + corresponding tCO₂e avoided) is narrated as Leadership Indicator
• RECs retired against grid-purchased electricity convert that quantum from location-based grid-mix Scope 2 to market-based zero-emission Scope 2 under GHG Protocol Scope 2 Guidance
• Both location-based + market-based Scope 2 figures should be disclosed (dual reporting)

Water + waste material profile

Water (thermal generation)

Thermal power is the largest industrial water user in India. A typical 1,000 MW coal plant consumes 3-4 cubic metres of water per MWh generated for cooling — adding up to ~24-32 million m³ / year at 80% PLF.

• Once-through cooling (older plants near rivers / coast): high withdrawal, lower consumption (most water returned to source); thermal pollution concerns
• Closed-loop cooling with cooling tower (most newer plants): lower withdrawal, higher consumption (water evaporates to atmosphere); cooling tower blowdown is the main wastewater stream
• Air-cooled condensers (dry cooling): very low water use; lower thermal efficiency (~3-5 pp loss); rare in India outside specific water-stressed sites

The Water Withdrawal Intensity Core attribute captures all withdrawal categories — surface, groundwater, third-party, seawater (for coastal plants), other. Make-up water for cooling towers is the largest category; the Leadership-indicator water-stressed-area disclosure flags any plants in WRI Aqueduct high-stress or extreme-stress zones.

Coal ash + FGD gypsum

• Fly ash + bottom ash are the dominant non-hazardous waste streams from coal plants — a 1,000 MW unit generates ~3-4 million tonnes / year of ash. Utilisation as supplementary cementitious material (in cement + concrete) is a key circularity opportunity + is mandated by MoEFCC notification (90%+ utilisation target).
• FGD (Flue Gas Desulphurisation) gypsum is a non-hazardous waste from SO₂ removal — utilised in gypsum board manufacture + cement.
• Hazardous waste — spent oil from turbine + auxiliaries, contaminated insulation, asbestos (legacy), spent ion exchange resin from water treatment.

The Embracing Circularity Core attribute captures fly ash + bottom ash + hazardous waste with the recycled / reused / disposed split. Ash utilisation % is the headline circularity narrative for a coal plant + is often disclosed prominently.

Material disclosures by NGRBC Principle

Principle 1 — Ethics, Transparency + Accountability

Power-sector entities have material exposure on:

• Compliance with Electricity Act + state ERC orders
• Anti-competitive conduct (market power in regional generation, vertical integration with distribution)
• Cybersecurity (grid SCADA + EMS systems are critical infrastructure)

Principle 2 — Sustainable Products + Services

• Lifecycle carbon footprint of power generation by fuel mix
• For renewable IPPs — solar panel + wind turbine end-of-life under EPR framework
• Electric mobility infrastructure (EV charging, smart grid integration)

Principle 3 — Employees + Workers Wellbeing

• Safety Metrics — LTIFR + Fatalities is highly material — high-voltage + height + confined-space work
• Contractor worker LTIFR typically 2-4× employee LTIFR
• Gender Diversity — historically low female representation in operations + field roles; improving through dedicated programmes

Principle 4 — Stakeholder Engagement

• Land acquisition + project-affected persons (for new plants + transmission ROW)
• Tribal + forest dweller consultation (Forest Rights Act 2006 applicability)
• Local community concerns around air + water pollution from thermal plants

Principle 5 — Human Rights

• Migrant worker housing + welfare (especially at coal mines + remote thermal sites)
• Tribal land rights in mining + transmission corridors

Principle 6 — Environment

• All 4 environmental Core attributes (GHG, water, energy, waste) are material
• SO₂ + NOx + PM10 + PM2.5 air emissions per MoEFCC standards
• Ash pond + ash dyke management — historical incident risk
• Water-stressed area disclosure for thermal plants in inland arid regions
• Biodiversity around large reservoirs (hydro) + transmission corridors

Principle 7 — Public Policy

• Industry-association advocacy (CII Power Council, IEEMA, IWPA)
• Position on coal phase-out, CCTS / PAT integration, RPO trajectory

Principle 8 — Inclusive Growth

• Rural electrification programmes (Saubhagya, DDUGJY)
• Reliable power supply to agricultural + rural consumers
• Job creation in smaller towns (thermal plant + transmission substation locations)

Principle 9 — Customer Value

• Distribution service quality — SAIFI (frequency) + SAIDI (duration) outage metrics
• Customer grievance redressal under CGRF
• Smart meter rollout + consumption transparency

Audit findings specific to power sector

1. CEA factor used for own generation Scope 1. The CEA grid emission factor is for grid-purchased electricity consumed. For a thermal genco’s own generation, Scope 1 uses fuel-input × IPCC emission factor — NOT the CEA factor.
2. Net vs gross generation confusion. Per-MWh intensity should be based on net generation (gross minus auxiliary consumption), not gross. Different denominators yield different reported intensities; the methodology section must be clear.
3. CCTS target overlap with PAT baseline. PAT-VIII (currently running) and CCTS thermal-power targets cover the same generating units. Transition rules + ESCert↔CCC conversion ratios are notified by BEE; the disclosure should clearly state the prevailing regime for the cycle.
4. REC retirement claimed without certificate retirement. Some entities report RPO compliance based on REC purchase without actual retirement on IEX / PXIL. The retirement step (which extinguishes the certificate) is the legally binding event for compliance.
5. SF₆ leakage under-reported. Annual SF₆ inventory + leakage calculation is often missing from transmission entities’ Scope 1 — yet GWP-23,500 means small leakage volumes translate to large tCO₂e quantities.
6. Ash utilisation % over-claimed. Cement + brick + road-aggregate offtake of fly ash should be tracked at the offtake-confirmation stage (not at the dispatch stage). Some entities count dispatches that don’t convert to actual utilisation by the offtaker.
7. Hydro reservoir emissions ignored. Large hydro reservoirs (especially in tropical zones) can have material biogenic methane emissions from submerged biomass decay. The IPCC 2019 Refinement guidance covers reservoir emissions; few Indian hydro entities currently report this.
8. T&D loss decomposition missing. Total T&D loss should be split between technical losses (resistive + transformer + transmission losses) + commercial losses (theft + billing inefficiencies). The decarbonisation lever differs for each.

EU CBAM exposure

Power generation is NOT in the initial CBAM scope (CBAM covers cement, steel, aluminium, fertilisers, hydrogen, electricity — but the electricity carve-out is specifically for cross-border electricity flows into the EU). Indian gencos that export to EU buyers (rare; cross-border electricity flows are geographically limited) would be in scope; most domestic Indian generation has no CBAM exposure.

However, gencos that supply electricity to EU-bound exporters of CBAM-scoped goods (steel, cement, aluminium) are indirectly affected — the buyer’s CBAM cost is influenced by the carbon intensity of grid electricity supplying their plants. This creates competitive pressure on gencos to demonstrate low-carbon generation in their commercial sustainability narratives.

For the CBAM mechanism + scope, see the CBAM glossary entry.

Connecting BRSR Core to other regimes

Regime	Power-sector intersection
CCTS	Thermal power is a notified obligated sector; sectoral targets in tCO₂e per MWh
PAT Scheme	Thermal power has been a PAT obligated sector since 2012; transitioning to CCTS
RPO + REC (Electricity Act 2003)	Distribution + obligated consumers must meet renewable %; REC retirement
IFRS S2	Scenario analysis particularly relevant — power-sector strategic planning hinges on climate-scenario electricity demand + fuel-mix evolution
SBTi	SBTi Power Sector Pathway provides specific decarbonisation trajectory; some Indian gencos (Tata Power, JSW Energy) have SBTi commitments
GRI 305	GRI 305 emissions disclosure framework parallels BRSR P6

How BatchWise routes BRSR Core engagements for power-sector entities

For Top 1,000 power-sector entities, the partner CA firm assurance scope typically includes:

• All 9 BRSR Core attributes under SAE 3000 (Revised) reasonable assurance
• Verification of CCTS cycle target + actual + CCC activity
• REC retirement reconciliation to IEX / PXIL transaction records
• SF₆ inventory + leakage estimation (for transmission entities)
• Fly ash + FGD gypsum utilisation reconciliation
• Water-stressed area disclosure (for thermal plants in inland arid regions)
• Safety incident reconciliation across employee + contractor worker cohorts
• LTIFR person-hours denominator verification

For the engagement that produces the signed assurance opinion, see BRSR Core Assurance. For standalone GHG verification under ISAE 3410 for power-sector entities (often required for international PPA buyers or sustainability-linked-loan covenants), see ISAE 3410.

Related reading

• CEA Grid Emission Factors — V21 (2025) state-wise + regional factors
• GHG Emission Intensity per Revenue — BRSR Core sibling
• Energy Footprint Disclosure — BRSR Core sibling
• Water Withdrawal Intensity — BRSR Core sibling
• Embracing Circularity — Waste — fly ash + FGD gypsum reporting
• Safety Metrics — LTIFR + Fatalities — employee + contractor split
• CCTS — Carbon Credit Trading Scheme — thermal power sectoral compliance
• PAT Scheme — predecessor energy-efficiency regime
• NGRBC Principle 6 — Environment — parent pillar
• BRSR Core Assurance — service