By Sandesh Naik, Chief Financial Officer, AB Energia Solutions
There is a number that deserves more attention than it has received. 102 GW. That is India’s assessed floating solar potential, mapped by National Institute of Solar Energy (NISE) and released by the Ministry of New and Renewable Energy (MNRE) in the “Report on floating solar PV potential assessment of India” in June 2026. It takes India’s total assessed solar potential to 3,445 GWp – 3,343 GW from ground-mounted installations, and 102 GW sitting quietly on the surfaces of reservoirs, irrigation tanks and water bodies spread across the country. Unlocking even a fraction of this dormant resource will be pivotal to achieving India’s 500 GW non-fossil energy target and accelerating corporate decarbonization.
To put that in perspective, 102 GW is nearly equivalent to the total solar capacity India has installed over the past two decades. And today, we have deployed roughly 600 MW of it. That gap, between what is possible and what exists on the ground, is not a failure of ambition. It reflects where the sector is in its natural arc of development. For years, India’s renewable energy story has been told through a single geography: the sun-drenched deserts of Rajasthan, the flat expanses of Gujarat, the vast open terrain of the southern plateau. Floating solar asks us to look somewhere else entirely. It asks us to look down – at the water.
The land question needs to be addressed
India’s solar ambition is not in question. The target is 500 GW of non-fossil fuel capacity. The manufacturing infrastructure is being built. The policy machinery is functioning. But there is a structural consideration that is becoming an increasingly important part of the sector’s planning conversation: land.
Land acquisition has become one of the more time-consuming and complex aspects of utility-scale renewable energy development driving up soft costs and timeline risks. Large contiguous parcels near transmission infrastructure and demand centres are increasingly difficult to assemble, particularly in densely populated states where power demand is highest. The states that have historically led India’s solar story: Rajasthan, Gujarat, and Tamil Nadu, have built their capacity partly on geographic advantage that is not equally distributed across the country.
The NISE report changes the conversation
What NISE report does is convert floating solar from a conversation about potential into a conversation about specifics. In the NISE applied rigorous screening criteria: hydro-lake water bodies with a minimum area of 10 hectares, year-round water availability, depths between 3 and 30 metres, minimum global horizontal irradiation of 4.5 kWh per square metre per day, and proximity within 10 km of both road networks and electrical substations. Of the 10,725 square kms of mapped water body area across India, NISE identified 4,546 square kms as suitable, and applying a conservative 20 per cent utilisation cap yields the 102 GW figure.
The state-level picture is equally revealing. Maharashtra leads at 16.28 GW, followed by Madhya Pradesh at 14.89 GW, Karnataka at 13.69 GW, Odisha at 12.81 GW and Telangana at 10.72 GW. This ranking diverges from India’s established ground-mounted solar geography – Odisha and Telangana, for instance, rank well ahead of Gujarat, Rajasthan and Tamil Nadu, which have traditionally dominated India’s solar capacity addition.
This geographical reordering matters. States that have played a secondary role in the solar story find themselves holding significant floating solar potential. These states have the water, the irradiation and the demand. What they have needed is the policy framework and the project pipeline to match.
What floating solar will offfer
On the economic side, floating solar projects carry approximately 25 per ent higher upfront investment compared to conventional ground-mounted installations. The floating structures, anchoring systems, corrosion-resistant cabling and engineering requirements of working on water all contribute to capital cost. This is a real consideration that the sector needs to address honestly as it scales. But the cost picture is more complete when viewed alongside what floating solar delivers in return.
The cooling effect of water reduces panel temperatures, improving energy generation efficiency and increasing annual electricity output by an estimated 5 to 10 per cent compared to ground-mounted systems. Floating installations can also reduce water evaporation from reservoirs by 30 to 60 per cent by blocking direct sunlight – a benefit that carries its own economic and environmental value, particularly in water-stressed regions and for thermal/industrial power plants relying on captive reservoir water. They also help suppress the growth of algae in water bodies.
And there is the land consideration. When a project is developed on a reservoir, the complexities of land acquisition such as negotiation, legal processes, timeline risk are substantially reduced. That saving is not always visible in a line-item cost comparison, but it is very real in project development experience. Viewed holistically, the economics of floating solar are more competitive than an upfront cost comparison suggests, and they will continue to improve as the sector scales and domestic manufacturing ecosystems mature.
The policy window that is now open
The MNRE has signalled that a dedicated scheme to accelerate floating solar deployment is in development. This is a meaningful moment for the sector. A well-designed framework can address three areas that the current environment leaves underserved.
The first is regulatory coordination. Floating solar projects today require engagement with multiple authorities like irrigation departments, water resource agencies, state nodal bodies, environmental authorities and discoms; through separate processes that can significantly extend development timelines. A more integrated approval mechanism, drawing on models India has applied in other infrastructure sectors, could improve predictability considerably for developers and investors.
The second is financial support calibrated to where the sector is in its development curve. Viability gap funding, concessional financing and blended finance structures can improve project economics during the scale-up phase and enable the kind of tariff discovery that attracts broader private capital over time.
The third is state-level project pipeline creation. The potential is documented. Converting it into commissioned capacity requires investment in site identification, grid connectivity assessment and environmental baseline studies – foundational work that government agencies are well-placed to lead, and that reduces the risk and cost burden on individual developers while paving the way for smooth green financing and debt syndication.
The hybrid opportunity
One dimension of floating solar that merits more attention in Indian policy discussions is its compatibility with existing hydropower infrastructure. Hybrid floating solar and hydropower systems can generate solar electricity during daylight hours while conserving water for hydropower generation at night or during periods of low solar output. This complementarity is genuinely useful for grid management. Floating solar panels generate at peak when the sun is high; hydropower can be held in reserve and dispatched when solar generation tapers. Together, they can create a more despatchable clean energy system on a single site, making use of existing transmission connectivity. Furthermore, co-locating solar with hydro optimizes land use and significantly improves the project’s overall return on capital employed, accelerating payback periods for developers and institutional investors.
For states like Odisha, Karnataka and Maharashtra, which have both significant hydropower assets and the highest assessed floating solar potential, this represents a real near-term opportunity, not a distant technology proposition. It needs a policy home that enables developers to structure hybrid projects efficiently.
What the gap between 102 GW and 600 MW tells us
The distance between potential and deployment in floating solar is not primarily a technology gap. The technology is proven. Succesful projects demonstrate that floating solar performs: the efficiency gains from water cooling are real, the operational characteristics are well understood, and the reservoir utilisation model works in practice.
The gap is structural. It reflects the absence of a consolidated approval framework, the lack of standardised technical guidelines that give developers and lenders a shared reference point, and a financing environment that is still calibrating its understanding of floating solar’s risk profile relative to ground-mounted projects. It also represents a major environmental, social, and governance win; by utilising unutilised water bodies, floating solar preserves arable land for agriculture and significantly reduces the carbon offset footprint of industrial off takers. It also reflects the early stage of project pipeline development, the kind of visibility that draws capital at scale has not yet been created for this segment.
These are addressable gaps. They have been addressed before, in other segments, when the right combination of policy intent, institutional coordination and financial support was assembled. India did not reach 155 GW of installed solar capacity by accident. It reached that milestone through policy frameworks, manufacturing ecosystems and procurement pipelines that progressively reduced risk and attracted capital at scale.
Floating solar is ready for similar attention – not as a niche or a supplementary segment, but as a meaningful pillar of India’s next energy chapter. The NISE report has provided the foundation. The policy intent has been signalled. The technology is proven. The next step is translating that alignment into a project pipeline that developers and investors can build on.
