India’s Power Sector Enters Phase of Grid Consolidation Post-Record Additions

Following record renewable energy (RE) capacity additions in FY26, the Indian power sector has established a new operational baseline. This milestone has prompted the Ministry of Power (MoP) to pivot its strategic priority from “raw capacity expansion” toward a sophisticated phase of “grid consolidation.” This transition focuses on integrating massive intermittent capacity into a stable, compliant national grid while harmonizing the complex regulatory landscape governing generators and consumers.

The Regulatory Framework: Transitioning from RPO to RCO

A central pillar of this consolidation is the MoP’s Gazette Notification on Renewable Consumption Obligation (RCO), issued August 5, 2025. This move shifts the sector’s regulatory weight from the Renewable Purchase Obligation (RPO) under the Electricity Act, 2003, to the RCO framework under the Energy Conservation Act, 2001.

While the framework targets a 50% non-fossil fuel share by 2030, the immediate RCO trajectory is defined by specific bounds:

Note: Targets represent the minimum share of total electrical energy consumption from renewable sources. Middle-year increments follow a strict upward trajectory to reach 2030 goals.

The “Designated Consumer” Threshold Loophole

The transition introduces a critical change in terminology, moving from “Obligated Entities” to “Designated Consumers” (DCs). Under the Energy Conservation Act, DCs—including distribution licensees, open access users, and captive power plants—are typically identified by specific energy consumption thresholds measured in metric tons of oil equivalent.

From a policy perspective, this creates an “exclusion risk.” Under the Electricity Act, 2003, all open-access consumers were obligated to meet RE targets regardless of size. The current RCO draft may inadvertently exclude open-access consumers falling below the notified DC threshold, potentially diluting the compliance base and complicating the broader objective of renewable integration.

Pillar I: Transmission Infrastructure and Addressing Bottlenecks

Grid consolidation requires the elimination of technical bottlenecks that lead to trippings and stranded capacity. Recent regulatory interventions signal a move toward localized system strengthening:

• Regional Integration: The Central Electricity Regulatory Commission (CERC) has adopted transmission tariffs for the Rajasthan Renewable Energy Zone (REZ) Phase-III (Parts H1 and H2). These projects, executed by Resonia Power Limited on a Build-Own-Operate-Transfer (BOOT) basis, are vital for high-volume evacuation from Western India.
• Biomass Evacuation: In Haryana, the State Commission (HERC) directed utilities UHBVN and HVPNL to prioritize evacuation for a specific paddy-straw based (biomass) power plant. Utilities must implement upgrades—such as new 132 kV lines or 22.5 MVA step-up transformers—to ensure dedicated supply and prevent frequent trippings.
• Captive Connectivity: The framework reinforces the right of captive generating plants (CGPs) to construct and operate dedicated transmission lines, ensuring reliable self-consumption and reducing grid reliance.

Pillar II: Enforcement Mechanisms and Technical Contentions

The enforcement of RE obligations has become more rigorous, yet remains clouded by regulatory inconsistencies. DCs may fulfill obligations through direct consumption, the purchase of Renewable Energy Certificates (RECs) including virtual PPAs, or a “buyout price.”

The “Buyout” vs. Penalty Debate

A significant point of technical contention is the treatment of the “buyout price.” While currently presented as a compliance method, analysts argue that treating a payment as “compliance” rather than a penalty undermines the Energy Conservation Act’s intent of fostering actual energy savings.

Further technical nuances include:

• DRE Non-Fungibility: Distributed Renewable Energy (DRE)—defined as projects below 10 MW, including rooftop solar—is non-fungible. Shortfalls in DRE cannot be offset by other RE sources unless a surplus in DRE exists.
• Nuclear Exclusion: The RCO explicitly excludes nuclear power from the definition of non-fossil sources. This is viewed by technical journalists as inconsistent with the broader national goal of maximizing all non-fossil energy forms.
• Funding Discrepancies: There is persistent ambiguity regarding penalty distribution. While the Draft Energy Conservation (Compliance Enforcement) Rules, 2025 suggest a 90% share for States and 10% for the Center, other RCO documents indicate a 50:50 split, creating a regulatory risk for long-term fund planning.

Pillar III: The Push for ‘Firm and Dispatchable’ Power and BESS

Consolidation is driving a shift from intermittent RE to “Firm and Dispatchable” supply. This transition relies heavily on Battery Energy Storage Systems (BESS) for peak demand management and cost optimization.

Key recent approvals highlight the integration of financial incentives with storage deployment:

• Peak Availability Mandates: HERC approved a Power Sale Agreement (PSA) between SJVN and the Haryana Power Purchase Centre (HPPC) that requires 90% availability during peak hours, specifically to mitigate the state’s projected power deficits.
• VGF-Backed Storage: The Uttar Pradesh (UPERC) approved 375 MW/1500 MWh of BESS for UPPCL utilizing Viability Gap Funding (VGF) through SJVNL. Similarly, TNERC approved land leasing for 501 MW/1000 MWh projects under the MoP’s VGF scheme.
• Regulatory Surplus Utilization: In Kerala, KSERC ratified large-scale BESS at Sreekantapuram, Mulleria, and Areacode, notably allowing the use of “available regulatory surplus” to fund these assets.

Regulatory Risks to Grid Stability

The consolidation phase faces several technical and legal hurdles that require urgent clarification:

• Jurisdictional Duality: Friction exists between the Electricity Act, 2003 (governed by SERCs) and the Energy Conservation Act, 2001 (governed by the BEE). In states like Kerala, where RPO trajectories are higher than national RCO targets, it remains unclear which penalty mechanism takes precedence in the event of a shortfall.
• Holding Company Aggregation: The draft allows compliance reporting at the holding company level. This poses a monitoring risk, as individual plant-level accountability is diluted, and SERCs may lack the authority to audit facilities located outside their specific state jurisdictions.
• The “Auxiliary Consumption” Legal Conflict: The RCO draft excludes auxiliary consumption from captive DC obligations. This contradicts the Supreme Court precedent set in State of Mysore v. West Coast Paper Mills Ltd. (1975), which established that electricity consumed for the further generation of power constitutes “consumption.”
• Fixed Multiplier Ambiguities: The use of a fixed multiplier (4 kWh/kW/day) for estimating generation from unmetered DRE installations fails to account for regional variations in solar insolation. Analysts recommend a shift toward region-specific Capacity Utilization Factor (CUF) benchmarks.

The Road Ahead for Grid Stability

India’s trajectory toward a 50% non-fossil fuel share by 2030 is now dependent on the institutional strengthening of the BEE and State Electricity Regulatory Commissions. The transition from capacity addition to grid consolidation demands a harmonized framework that resolves the “duality of jurisdiction” and clarifies technical definitions—such as “consumer’s network”—that currently invite legal dispute. Achieving long-term grid stability will require moving beyond revenue-generating buyout mechanisms toward a system that prioritizes actual physical integration and dispatchability.