Rooftop Solar Cost in India 2026: What C&I Buyers Pay
By Hardik BhatiaPublished"What will it cost?" is the first question most businesses ask about rooftop solar - and the honest answer is a range, not a single number. The per-kW price of a commercial or industrial system in 2026 depends on how big it is, what components go into it, the state of your roof, and where you are. Understanding what moves the number is more useful than any headline figure, because it lets you read a quote critically rather than take it on faith.
There is no single national price for C&I rooftop solar in India in 2026. Project cost varies significantly with system size, module technology and sourcing, roof conditions, site complexity, location, and applicable grid-connection requirements — which is why a per-kW figure from one project rarely transfers to another. Larger systems often achieve lower per-kW costs as engineering, procurement, and installation costs spread across more capacity, but complex sites can sit well above any general figure. The per-kW capital cost applies under the CAPEX model; under OPEX, the customer typically does not fund the system's upfront capital expenditure.
Here's the full picture for CFOs and sourcing heads - including why the number moves the way it does, and how to read a quote critically.
What does C&I rooftop solar cost per kW in 2026?
There is no single, reliable national per-kW price for C&I rooftop solar in India in 2026 — real project costs vary too widely for a headline number to be meaningful. What is reliable is the shape of the variation: per-kW cost generally falls as capacity grows, because modules, mounting, balance-of-system, and labour costs spread across more capacity — though this isn't universal, since complex roofs, long cable runs, structural reinforcement, or high-voltage interconnection can push larger projects higher.
Real 2026 projects illustrate the spread better than any average. A 500 kW rooftop installation at the Delhi Vidhan Sabha was reported (in a May 2026 account of the project) at a budget of around ₹2.94 crore — roughly ₹58,800/kW — driven up by a heritage building, no-drilling constraints, an elevated 14-foot structure, and unusual engineering requirements. That is deliberately not a market benchmark; the example illustrates why site-specific engineering and structural requirements can materially affect project cost.
The practical takeaway for budgeting: treat any per-kW figure you see online as a rough orientation at best, then get a costed proposal for your actual site. Site specifics — not a headline rate — determine the real number.
A crucial distinction when reading any quote: panel price is not system price. The modules are only one component. A complete working system also includes the inverter, mounting structure, cabling, earthing, protection equipment, monitoring, and installation labour. When an installer quotes a per-watt or per-kW number, they should mean the complete installed system — always confirm what's included.
Why have some rooftop solar projects become more expensive in 2026?
One factor affecting rooftop solar costs in 2026 is India's changing module and cell sourcing requirements — but the impact is uneven and depends on the project type and timing. India's ALMM (Approved List of Models and Manufacturers) framework requires ALMM-listed modules for government, government-assisted, open-access, and net-metering projects. ALMM List-II requirements for domestically approved solar cells took effect from June 1, 2026. MNRE subsequently provided a limited exemption window through December 31, 2026 for eligible net-metering and open-access renewable-energy projects, subject to the conditions of the applicable order. MNRE also continues to update the ALMM lists, so buyers should verify the applicable list and project-specific exemption status before procurement.
The important nuance for C&I buyers: this applies most directly to net-metering and open-access projects, and the exact requirement now depends on the project's category, commissioning timeline, and applicable ALMM provisions. Private, non-subsidy-linked behind-the-meter projects may have different sourcing requirements depending on the applicable regulatory and grid-connection framework — so the cost impact varies by how and when your project connects to the grid, not across the board. The practical takeaway: buyers should verify the exact ALMM requirement applicable to their project before locking module procurement. We cover the rules in detail in our explainer on what ALMM List-II means for C&I buyers.
Industry data on the price effect is mixed rather than uniform. Mercom's Q1 2026 rooftop research indicated that average rooftop system costs remained relatively stable across most module technologies, while systems using Chinese modules saw a noticeable increase. In practice, ALMM-related sourcing requirements can create additional supply and pricing pressure for affected projects, though the impact varies by project type, commissioning timeline, sourcing strategy, and module technology. For budgeting, the practical implications are two: quotes prepared before mid-2026 may not reflect current sourcing rules for a covered project, and compliant module supply can affect both price and project timeline.
What factors change the final price of a solar system?
Beyond system size, five factors move the number most. Understanding them helps you compare quotes on a like-for-like basis rather than on headline price alone:
Module technology. Mono PERC, TOPCon, and bifacial modules differ in price and yield. Bifacial modules can deliver additional output where the installation provides sufficient rear-side irradiance, although the benefit depends strongly on roof reflectivity and mounting configuration.
Inverter quality. A higher-grade inverter with more MPPT inputs and remote monitoring costs more upfront but can reduce downtime and shading losses over the asset's life.
Roof type and structure. Metal-sheet roofs can often be economical to mount on, depending on the roof structure and mounting system; RCC roofs need mounting structures; older or fragile asbestos-containing roofs may require additional structural assessment or alternative mounting arrangements, which can increase project cost. A structural assessment is essential before finalising.
Site complexity. Cable-run lengths, skylights and ducting that reduce usable area, shading from adjacent structures, and access all affect cost.
Location. Prices can vary across states due to logistics, state-specific regulations and metering arrangements, and DISCOM requirements.
This is why two "100 kW systems" can carry very different price tags — and why the cheapest quote is not automatically the best value. A lower-priced quote may use different component specifications, structural assumptions, warranties, or O&M provisions, which can affect lifetime economics.
Do C&I buyers get a subsidy on rooftop solar?
No central PM Surya Ghar CFA applies to C&I systems. The central PM Surya Ghar subsidy is for residential consumers; commercial and industrial rooftop systems do not receive this residential central financial assistance (CFA). This is a common point of confusion, because much of the online pricing content is written for homeowners who do receive a subsidy.
What C&I buyers may instead benefit from are financial mechanisms that improve returns for an eligible business: available tax benefits such as depreciation on the asset (subject to the prevailing provisions and your tax position), potential GST input credit (subject to GST rules), and the ongoing savings from displacing high-tariff grid power. We explain how these interact with ownership in our OPEX vs CAPEX guide. SustVest is not a tax advisor, and eligibility should be confirmed with your finance team.
How does the funding model change what you pay upfront?
The cost figures discussed above are the capital cost of owning the system — which you pay only under the CAPEX model. Under CAPEX, you fund the system (from capital or debt), own the asset, and capture the full economic benefit. Under OPEX/RESCO, a developer typically funds and owns the system, and you buy the electricity generated under a contracted per-unit tariff structured to be competitive with your applicable grid electricity cost.
So the real "cost" question has two forms. Under CAPEX, it's the capital cost per kW against a payback period. Under OPEX, it's the effective cost of solar electricity against your applicable grid electricity cost — OPEX can eliminate the customer's upfront capital expenditure, though structures may still involve deposits or interface costs. Which framing matters depends entirely on which model fits your balance sheet and tax position.
What does the cost mean for payback and savings?
For an eligible tax-paying business with strong daytime consumption, a CAPEX system can often target payback in roughly 3–6 years, after which the system delivers lower-cost power over the remainder of its operating life. Payback depends on your tariff, how much generation you self-consume, the funding model, and your tax position — the same variables we break down for factories in rooftop solar for manufacturing plants. Verified 2026 examples show the lower end of that range: Mercom reported an expected payback of around 2.5 years for a Gujarat fabric maker's 450 kW rooftop system, and around 3.5 years for fabric manufacturer G.M. Syntex's 3 MW installation. Real-world paybacks can range from around 2.5 years upward, depending heavily on tariffs, self-consumption, and project cost.
The cost of the system is only half the equation; the other half is how well it's designed and run. Under the applicable state and DISCOM billing framework, savings depend heavily on self-consumption (see net metering vs net billing), and long-term returns depend on the system actually delivering its designed output — which is where component quality and O&M matter. The lowest-cost system is rarely the highest-return one.
The bottom line for C&I buyers
There is no single 2026 national price for C&I rooftop solar in India — real project costs vary too much by configuration, sourcing, roof, and site for a headline number to be meaningful. What matters is understanding what moves the number, and reading every quote critically: confirm what's included, compare like-for-like, and weigh lifetime value over upfront price. The cheapest quote is rarely the best value, and under OPEX the upfront cost question disappears entirely. The most reliable price for your facility is a costed proposal built on your actual roof, load, and grid connection — not a figure borrowed from another project.
SustVest provides transparent, itemised pricing for rooftop solar under both CAPEX and OPEX models, designed around your roof, load, and tariff — recognised as a CRISIL Top-10 Rooftop Solar Developer in India (2025), with 83+ projects delivered across 13+ states. Book a free site assessment for a costed proposal based on your facility, not a generic figure.
Frequently Asked Questions
How much does commercial solar cost per kW in India in 2026? There is no single national price for C&I rooftop solar in India in 2026. Project cost varies significantly with system size, module technology and sourcing, roof type, site complexity, location, and applicable grid-connection requirements. Per-kW cost generally falls as system size rises, but complex sites can cost considerably more. A costed proposal for your specific site is the only reliable figure.
How much does a 100 kW solar system cost for a business? The cost of a 100 kW C&I rooftop system depends on module technology, roof structure, installation complexity, sourcing requirements, and location, so there is no single reliable national figure for 2026. Per-kW costs are generally lower than for very small systems but higher than for large MW-scale plants. The accurate number for your building comes from a site-specific costed proposal.
Why is commercial solar more expensive for some projects in 2026? India's changing module and cell sourcing requirements under the ALMM framework can create supply and pricing pressure for affected projects. ALMM List-II requirements for solar cells took effect from June 1, 2026, while MNRE subsequently provided a limited exemption window through December 31, 2026 for eligible net-metering and open-access projects, with compliance applying from January 1, 2027. The impact therefore depends on project type, commissioning timeline, sourcing strategy, and applicable regulations. Industry data on the price effect is mixed, with some reporting indicating costs stayed relatively stable across most module technologies while systems using Chinese modules rose.
Do businesses get a government subsidy for rooftop solar? No. The central PM Surya Ghar CFA is for residential consumers; commercial and industrial rooftop systems do not receive this residential central financial assistance. C&I buyers may instead benefit from applicable tax mechanisms and energy cost savings, subject to their tax position.
What is the payback period for commercial rooftop solar? For eligible tax-paying businesses with good daytime consumption and reasonable tariffs, a CAPEX system can often target payback in roughly 3–6 years, followed by lower-cost power over the remainder of its operating life. Real 2026 examples include around 2.5 years for Prem Industries' 450 kW rooftop project and around 3.5 years for G.M. Syntex's 3 MW project. Actual payback varies with tariff, self-consumption, system cost, financing, and tax position.
Is it cheaper to install solar through OPEX or CAPEX? Under CAPEX you pay the capital cost upfront and own the system; under OPEX you buy the power at a per-unit tariff. OPEX can eliminate the customer's upfront capital expenditure, while CAPEX can provide stronger long-term economics where the customer can efficiently fund and own the asset. Which is "cheaper" depends on financing cost, tax position, tariff, and self-consumption.
Sources
Mercom India Research — Q1 2026 rooftop market report (rooftop costs relatively stable across most module technologies; Chinese-module increase); verified project paybacks: Gujarat fabric maker (Prem Industries) 450 kW ~2.5-year payback; G.M. Syntex 3 MW ~3.5-year payback; ALMM behind-the-meter distinction
EQ Magazine / developer account — Delhi Vidhan Sabha 500 kW project, ~₹2.94 crore budget (May 2026), used only to illustrate cost variability on a complex heritage site
MNRE / PIB — ALMM List-I framework; List-II applicability from June 1, 2026; July 18, 2026 limited exemption window for eligible net-metering and open-access projects through December 31, 2026; PM Surya Ghar residential CFA guidelines
SustVest — 83+ projects delivered, 13+ states, CRISIL Top-10 Rooftop Solar Developer in India (2025)
Historical context only (NOT a 2026 figure): JMK Research / IEEFA, "Emerging Technology Trends in the C&I Rooftop Solar Market in India," July 2021 — early installation-cost benchmarks. Deliberately not used as a current price in this post.