India Approves ₹14,500 Crore Scheme for 92 GWh Energy Storage Capacity

The Union Cabinet on 4 November 2026 approved a ₹14,500 crore Viability Gap Funding scheme to develop 92 gigawatt-hours of grid-scale energy storage capacity between FY27 and FY31. The measure is intended to strengthen the power grid and support higher integration of renewable energy so that green power can be supplied on a more continuous basis.

Of the 92 GWh target, 60 GWh will come from hydro pumped storage plants, 30 GWh from battery energy storage systems and 2 GWh from alternative technologies. The projects are expected to attract an estimated investment of ₹97,600 crore. Capacity will be awarded through tariff-based competitive bidding. Battery projects must meet a minimum domestic content requirement of 40 percent.

The new capacity equals 170 percent of India’s existing grid-scale energy storage. It is meant to help meet an estimated requirement of 411 GWh by 2031-32. Public and private distribution companies can claim support for both battery and pumped-storage projects. The funding improves financial viability and is expected to accelerate deployment of large-scale storage infrastructure.

The scheme sits alongside a separate Cabinet approval the same day for a ₹2,814 crore capital expenditure support programme to promote domestic processing of critical minerals over the same five-year period. Together the two decisions address storage and the supply of materials needed for batteries and other clean-energy equipment.

India’s renewable capacity has expanded rapidly, but variable generation from solar and wind requires storage if the grid is to absorb larger shares without curtailment or reliance on thermal backup during evening peaks. Pumped hydro provides longer-duration storage using existing or new reservoirs. Batteries offer faster response and can be sited closer to demand centres. The 40 percent domestic content rule for battery projects is intended to support local manufacturing of cells and packs.

Viability gap funding bridges the difference between the cost of a project and the tariff that buyers are willing to pay. By reducing the effective capital cost, the scheme lowers the bid tariffs that developers must recover. This is particularly relevant for storage, where capital costs remain high relative to the revenue streams available under current market rules. The government has used similar funding in the past for transmission and renewable projects that faced viability gaps.

The 92 GWh figure is substantial relative to current installed storage. Most existing capacity is in the form of pumped hydro at specific sites. Battery storage on the grid is still limited. Adding 30 GWh of batteries over five years would mark a clear step-up in electrochemical storage. The 60 GWh of pumped storage would require new or expanded plants, each with multi-year construction timelines. The two-gigawatt-hour allocation for alternative technologies leaves room for pilots of other approaches such as compressed air or thermal storage.

Distribution companies will be able to contract the capacity. This links the storage directly to the entities responsible for meeting demand. Tariff-based auctions are expected to produce price discovery and competition among developers. The domestic content requirement applies only to the battery portion, reflecting the higher import dependence of battery components compared with pumped hydro equipment.

The overall investment estimate of ₹97,600 crore implies an average capital cost in the range of roughly ₹1 crore per GWh across the mix of technologies, though actual costs will vary by project type and location. The ₹14,500 crore VGF represents a portion of that total, with the balance coming from developers, lenders and other sources. Exact per-project support will depend on the auction outcomes and the technology chosen.

The decision follows earlier steps to expand renewable capacity and to set targets for storage. Meeting the 411 GWh requirement by 2031-32 would allow a higher share of variable renewables while maintaining reliability. Without additional storage, further renewable additions risk higher curtailment or greater dependence on coal plants for balancing. The scheme provides a defined funding window and a clear capacity target against which progress can be measured.

Implementation will require coordination between the Ministry of Power, state utilities, developers and equipment suppliers. Pumped storage projects need environmental and land clearances in addition to technical design. Battery projects can move faster but face supply-chain and safety considerations. The five-year period from FY27 to FY31 gives time for both categories to come online in stages.

The parallel critical minerals scheme aims to reduce import dependence for materials used in batteries and other equipment. Domestic processing capacity for lithium, nickel and related minerals is currently limited. Building that capacity supports the battery portion of the storage programme and longer-term manufacturing goals. The two approvals on the same day indicate that storage deployment and materials security are being treated as linked priorities.

For the power sector, the immediate effect is a signal of continued policy support for storage. Developers and financiers now have a quantified funding mechanism and a capacity target. Distribution companies have a route to procure the services. The actual volume commissioned will depend on auction response, project execution and the evolution of market rules for storage revenue. The Cabinet decision sets the financial and capacity parameters within which those outcomes will be determined.