India’s small hydro subsidy should pay for dependable power

India has a case for supporting small hydro where a good site can supply power at hours when a remote grid needs it. The Cabinet on 18 March approved an outlay of ₹2,584.60 crore for projects of roughly 1,500 megawatts over five financial years from 2026–27. The scheme offers greater assistance in the north-east and districts on international borders. Those places can have attractive sites and costly alternatives for grid supply. The investment decision should turn on the value of electricity delivered through the year and the cost of doing so at a particular site. Installed megawatts alone give a poor measure of that return. Cabinet decision on small hydro · Business Standard, 18 March

The grant lowers a fixed cost and leaves several risks intact

The scheme covers projects from 1 to 25 MW. In the north-eastern and eligible border areas, the grant is limited to the lower of ₹3.6 crore per MW and 30% of project cost, with a ₹30 crore ceiling per project. Elsewhere, the corresponding figures are ₹2.4 crore per MW, 20% and ₹20 crore. The Cabinet statement expects the scheme to attract about ₹15,000 crore in investment and reserves ₹30 crore for detailed reports on roughly 200 projects. The investment figure is an expectation. The project reports are a chance to find out which sites are worth developing before larger sums are committed. Cabinet decision on small hydro

Consider a 12 MW plant that costs ₹120 crore. Under the preferential formula the per-MW amount is ₹43.2 crore and the percentage amount is ₹36 crore, so the ₹30 crore project cap binds. Elsewhere the comparable figures are ₹28.8 crore and ₹24 crore, and the ₹20 crore cap binds. The developer’s capital requirement after the grant is ₹90 crore in the first case and ₹100 crore in the second, before financing and other costs. The example isolates the grant. It does not imply that a plant in the first location will earn a better return. Civil works, construction delays, grid access and seasonal water flows can easily dominate the ₹10 crore difference. Cabinet decision on small hydro

Capacity utilisation shows why. At 45% utilisation, a 12 MW plant produces about 47.3 million kilowatt-hours in a 365-day year. At 30%, it produces about 31.5 million. The same annual fixed cost is spread across one-third fewer units in the second case, making the fixed cost per unit about 50% higher. The Central Electricity Regulatory Commission uses normative factors of 45% in several states, 40% in Punjab and 30% elsewhere for its small hydro tariff regulations. Those norms are useful benchmarks, while a feasibility study still needs site-specific hydrology and a realistic allowance for outages, silt and access to the network. CERC renewable tariff regulations

To put the scale in context, contemporaneous coverage puts existing small hydro capacity at about 5,100 MW across 1,196 sites. The proposed 1,500 MW would amount to about 29% of that installed capacity if built. Neither number tells us how much electricity will be available at the hour of greatest need. The existing fleet offers an evidence base. Before approving sites of similar design and geography, compare actual output and outage records from plants already running. If those plants routinely miss their dry-season estimates, use that evidence to lower the expected generation of new projects until the developers can show why their sites are different. Business Standard, 18 March

The grant arithmetic can also be converted into a price. Suppose the 12 MW project in the preferential area must recover its remaining ₹90 crore over 30 years at an assumed real financing rate of 8%. An annuity on those assumptions is about ₹8 crore a year. That is about ₹1.69 per unit of capital recovery at 45% utilisation and ₹2.54 at 30%, before operating costs, transmission, losses and taxes. These figures are neither tariff proposals nor social costs. A public appraisal must include the grant as part of total investment and compare the resulting resource cost with what the same budget could buy elsewhere.

The hour and location of generation determine its value

A unit of electricity supplied during a local shortage can be worth more than one supplied when the grid has surplus power. Small hydro can be valuable if water availability and local demand line up, or if it reduces the cost of moving power over a constrained network. A plant that generates most of its output during the wet season may deliver much less during a dry-season peak. A run-of-river plant with limited storage has less control over that timing than a plant with substantial water storage. A fair comparison therefore uses hourly or seasonal generation and local demand. Compare the site with alternatives that can serve the same hours, including grid reinforcement, solar plus storage or firm power procured from elsewhere. Cabinet decision on small hydro · CERC renewable tariff regulations

The strongest argument for an upfront grant is that new projects bear large construction and connection costs and investors may discount benefits that accrue to the local network. A project serving a weak grid can reduce outages or defer some upgrades that the developer cannot charge for directly. The grant can make that otherwise viable project financeable. The strongest reason to be selective is that a capital grant lowers the developer’s exposure to construction cost while leaving customers and taxpayers exposed to low generation later. Milestone payments can establish whether work was completed. A portion linked to verified delivery in critical hours would better align private incentives with the network benefit the subsidy is intended to buy. Cabinet decision on small hydro

River and community costs are part of the comparison

The Cabinet argues that smaller projects can avoid the large land and resettlement costs of major dams. Scale matters, yet even a relatively small diversion can affect downstream users, aquatic habitat and the movement of sediment. Several projects on the same river can have a cumulative effect that an appraisal of one project misses. The baseline for the evaluation should include existing irrigation, fisheries and drinking-water uses and the amount of water that remains available through dry months. Monitoring these effects should continue after commissioning. A project that clears its financial threshold because downstream costs are borne by others can still have a poor public return. Cabinet decision on small hydro

The same discipline applies to the jobs claim. The Cabinet projects 51 lakh person-days of work during construction and anticipates jobs in operation and maintenance. Person-days describe a flow of work and should be kept distinct from permanent jobs. The local gains depend on who is hired, whether earnings go to households near the project, and what workers would have earned elsewhere. Construction wages can be valuable in a remote district, particularly when work is scarce. The case strengthens if projects also leave durable maintenance jobs and more reliable power for local enterprise. Both outcomes are observable without treating the construction forecast as a result already achieved. Cabinet decision on small hydro

Choose projects against their alternatives

Publish the cost of generation and of connecting each proposed project, expected output by season, the terms of the power purchase agreement and the grant per unit of dependable supply. Show how the ranking changes under a dry year, delays in commissioning and lower prices for storage or competing generation. After commissioning, report actual output, outage hours and river-flow compliance against that appraisal. If plants supply electricity at the hours promised, support local activity and respect downstream requirements, the case for extending the programme strengthens. If construction targets are met while dry-season delivery is weak and costs rise, the project pipeline should be reassessed. The public purchase is more reliable energy at a competitive cost, and the capacity target is only a means of getting it.