Solar Project Financing

₹37.49 Cr Equity. 120 MWp Open Access Solar. 91.49% IRR. ₹2.89/unit Savings. The Board still didn't approve. Here is the story: The CFO of a Steel company in Maharashtra was planning a 120 MWp Open Access Solar project under a Group Captive structure. He presented the opportunity to the Board, asking for approval of a ₹37.49 Cr equity investment. The numbers were compelling: → IRR on Equity: 91.49% → Savings: ₹2.89 per unit → Total Project Cost: ₹480.7 Cr The Board was happy with the savings. They liked the IRR. But they didn't approve. Not yet. They asked very sharp questions: → What are the components that make up the ₹480.7 Cr project cost? → What is the exact cost breakup of the project? → How does taxation impact the total project cost? → What portion is hard cost (land and equipment) versus soft cost (services and financing)? → What is the debt-equity structure, and which developer is following it? The Board made it clear: "Until we get answers to these questions, we will not approve this investment." The CFO took on this challenge. He reached out to us to decode the Board's exact questions, so that he can go back with a Board-Ready cost anatomy and get the ₹37.49 Cr equity approved. We prepared the exact table for him. He took it back to the Board. They saw the full picture, every component, every percentage, every rupee accounted for. The Board approved the investment unanimously. I am sharing with you the exact table that the CFO used to get his Board approval. [Caution: The numbers in the table are illustrative and close to reality. We have not shared the exact figures due to their confidential nature.] Take a printout of this. Pin it in your notebook. So that when you are preparing your next Board presentation for an Open Access Solar project equity approval, you have a ready reckoner to decode your total project cost. Because when the Board asks, "Where exactly does the ₹480 Cr go?" you should have the answer ready. Not after the meeting. Before it. P.S. If you found this useful and want to know how project costs change when you scale from 120 MWp to 300 MWp or 500 MWp, and how economies of scale come into play: 👉 Type "COST" in the comment box below. 👉 Connect with me so that my team and I can DM you. 👉 Like this post. Follow Gaurav Kawatra for boardroom-grade Renewable Energy insights.

How to prepare financial proposal for Solar PV plant ? 1. Executive Summary Objective, Key Financial Metrics: Highlight key financial metrics such as total project cost, expected savings, ROI, and payback period. Summary of Funding Needs: Summarize the funding requirements and potential sources. 2. Project Description Project Overview, Project Scope. 3. Cost Estimates Capital Expenditure (CapEx): Equipment Costs, Installation Costs, Permitting and Licensing, Grid Connection Fees, Operational Expenditure (OpEx), Maintenance Costs, Operational Costs, Insurance. 4. Revenue Projections Energy Production Estimates Revenue Streams: Identify and describe all potential revenue streams, including: Sale of Electricity: Estimate revenues from selling electricity to the grid or directly to consumers, Incentives and Subsidies Renewable Energy Certificates (RECs): Include potential income from selling RECs or carbon credits. 5. Financial Analysis Cash Flow Analysis, Profit and Loss Statement: Prepare a projected P&L statement showing expected revenues, costs, and profits. Balance Sheet: Include a projected balance sheet for the project. 6. Return on Investment (ROI) Payback Period, Net Present Value (NPV), Internal Rate of Return (IRR): Determine the IRR to indicate the expected rate of return on the project. 7. Funding Strategy Funding Requirements: Clearly state the total funding required for the project. Sources of Funding: Equity Financing: Detail potential equity investors and their expected returns. Debt Financing, Grants and Subsidies, Funding Timeline. 8. Risk Analysis and Mitigation Financial Risks: Identify potential financial risks such as cost overruns, lower than expected energy production, and changes in regulatory policies. Mitigation Strategies: Describe strategies to mitigate these risks, such as contingency funds and performance guarantees. 9. Sensitivity Analysis Scenario Analysis: Perform sensitivity analysis to show how changes in key variables (e.g., energy prices, production levels) affect project financials. 10. Conclusion Summary of Financial Viability. Next Steps: Recommend the next steps for moving forward with the project, including securing funding and finalizing contracts. 11. Appendices Detailed Financial Models: Include detailed financial models and spreadsheets. Supporting Documents: Provide any supporting documents, such as quotes from suppliers, letters of intent from investors, and regulatory approvals. #solar #proposal #energy

I reviewed the latest TPO and net metering data across all 50 states. 17 of them have neither. If you’re an installer in one of those states, here’s what that means for you: The residential ITC expired December 31, 2025. States with strong TPO markets like California and Florida can still claim the 48E credit through 2027. That cushions the blow. But 17 states have zero residential TPO providers. Many also lack net metering. The states: Washington, Missouri, Minnesota, Arkansas, Idaho, Wisconsin, Indiana, Kentucky, Kansas, Montana, Nebraska, Wyoming, Tennessee, Alaska, South Dakota, Alabama, and North Dakota. Almost all have electricity rates below the national average of 16.48¢/kWh. Longer payback periods. Fewer financing options. Harder sell. pv magazine USA called these states potential “holes in the market.” I’d call them the places where the most creative installers will emerge. 5 options worth exploring: 1 - Lead with batteries, not panels. Battery-only installs cost $8,000-$15,000. Lower barrier. Simpler conversation. Once they have a battery, solar becomes the cheapest way to refuel it. The upsell happens naturally. 2 - Push into commercial and C&I. Commercial solar still has the 48E tax credit. Bigger projects, longer sales cycles — but the margins can be worth it. 3 - Build an O&M business. LightWave Solar, LLC in Tennessee lost net metering around 2018. They diversified hard. Today, more people doing O&M than installs. Their CEO says the business is stronger than it’s ever been. Recurring revenue, not project-based. And it keeps you in front of customers for upsells and referrals. 4 - Explore prepaid leases and new financing. Short-term TPO is emerging: 5-10 year prepaid leases where ownership transfers to the homeowner. Ohm Analytics reports adoption is “faster than expected.” Credit unions are stepping in too. 5 - Sell self-consumption, not net metering. Size systems to maximize usage, not exports. Pair with storage and EV charging. Installers in Tennessee and parts of Idaho have been doing this for years. The economics work when you’re offsetting usage, not relying on export credits. — When our previous solar company lost favorable policies, it forced us to get better at everything else. The installers in these states who figure it out now will build businesses that don’t depend on any single policy. And if they can grow with no ITC, no TPO, and no net metering — they can grow anywhere. Those are the companies that go nationwide. — If you’re in one of these 17 states, how are you adapting?

Sometimes, life pauses projects, and reengineering brings them back to life - especially when it helps cut the cost of a solar PV project by 42%. Almost all issues with stalled projects are tied to financial models. By achieving a 42% discount compared to 2019 costs, we were able to revive a previously frozen project. While even smaller cost reductions could have done the job, this significant improvement is sustainable and still allows suppliers to maintain high service quality. With limited funding, creative solutions are essential. This wasn’t our first re-engineering solution and you can even see some previous examples on Google Maps. This time, by re-engineering the project from 2019 designs to 2024 solutions, we reduced project costs by 22%.  Then, through strategic procurement, we cut equipment costs by another 20%—most of this came naturally from falling market prices. On top of that, the station’s efficiency increased by almost 8%. For an energy market known for its conservatism, these results are impressive. And the good news? They’re achievable for anyone who invests in proper re-engineering. Here’s a quick checklist to help determine whether your project needs re-engineering or if it’s still up-to-date: 1. Modules: If your project uses solar modules with a capacity below 580-600 W, it’s time to redesign with 610 W - 710 W modules. Higher capacity reduces costs for structures, cabling, and labor. 2. Voltage Levels: If your DC voltage is below 1500 VDC or your inverter AC voltage is below 800 VAC, re-engineering could save significantly on cable costs. 3. Inverters: Consider upgrading to higher-capacity inverters (330 kW is ideal). This reduces the amount of equipment needed, often by several times (not only by decreasing of quantity of inverters but also by ceasing of use of connection boxes). 4. Transformer Stations: If you planned small 1-2 MW transformer stations, look at 3-6-9 MW solutions. Fewer transformer stations mean lower costs and more space. Implementing any of these changes can pay for the re-engineering itself (if not, you’ve been sold an overpriced service). But since these updates typically require a full redesign, it’s better to address them all at once. Are your projects ready for today’s market solutions? #ReEngineering #RenewableEnergy #ProjectManagement #SolarPV

Why Rising Interest Rates Hit Renewables Harder Than Fossil Fuels Renewable energy is a capital story, not a fuel story. Unlike coal or gas plants that pay as they burn, solar and wind projects pay most of their cost upfront. Panels. Turbines. Batteries. Grid setup. Once built, fuel is free — but the financing isn’t. Here’s the catch: These projects are debt-heavy and rely on cheap capital to stay profitable. Most are financed through long-term Power Purchase Agreements (PPAs) that lock in cash flows for 15–25 years. So, when central banks (like the RBI) raise interest rates — the cost of debt jumps, and suddenly the math changes. Globally, a small 2% rise in interest rates can push the Levelized Cost of Energy (LCOE) for renewables up by nearly 20%. That’s a much bigger hit than fossil fuel projects, which are less CapEx-heavy. In India, our base cost of borrowing is already high — making renewable projects 24–32% costlier than similar ones in the U.S. And because tariffs (PPAs) are highly sensitive to financing costs, A 2% rate change can shift final power prices by about 7%. On top of that, India’s reliance on variable-rate debt means financing costs fluctuate with every RBI policy change — adding 13–14% structural risk to project costs. And then comes execution risk. Between 2022–2024, the Central Transmission Utility of India (CTUIL) cancelled grid access for 17 GW of delayed renewable projects — including those by Adani Green, ReNew Power, and NTPC. In total, nearly 38 GW of capacity has been cancelled since 2020. Why? Because high financing costs and grid delays make it difficult for developers to reach financial closure and start construction on time. When the cost of capital stays high, projects slow down, delays pile up, grid access is lost, targets fall short. India’s 500 GW renewable goal depends as much on cheap financing as it does on technology and policy. Until cost of capital eases and grid bottlenecks clear, money not sunlight remains the biggest barrier to renewable growth. #Finance #LinkedIn #Valuation

"It's like credit card debt. The longer you wait, the worse it gets." That's what one of our brilliant board members (Uma Devi Gopaldass CDI.D) told me last week when we discussed the biggest barrier to onsite energy deployment. It stopped me in my tracks and inspired me to write this article - https://lnkd.in/grYkUwHB Most companies are stuck in an energy debt spiral: → Utility rates are already high (and rising 4% on average annually) → Leadership keeps delaying energy investments → Next year, they pay even more for the same power → The company loses margin, cash flow, and control Meanwhile, onsite energy costs keep dropping. Here's the shocking part: In our recent webinar (link below on the OBBB), the #1 barrier wasn't complexity or regulation. It was "lack of capital." But here's the truth: You don't need capital to start. Just like swapping a high-interest credit card for a better payment plan, you can replace unpredictable utility bills with fixed, lower payments through Energy-as-a-Service. The numbers are illuminating, here are a few random project examples from a larger customer portfolio: Case 1: Small manufacturer in Massachusetts → Current bill: $750K/year (31% higher than 2020) → In 25 years: $2M+/year → With onsite energy: $938K NPV, 5-year payback Case 2: Large manufacturer in California → Current bill: $6.6M/year (72% higher than 2020) → In 25 years: $17.6M/year (potentially $90M+ at CA's 11% escalation) → With onsite energy: $12.4M NPV, 3-year payback These weren't even their best projects—ranked #100 and #42 out of 371 facilities. Three financing paths, same destination: → Self-financed: Highest returns, full control → Debt-financed: Cash flow optimized, leverage friendly → EaaS/PPA: Zero capital, transferred risk The portfolio impact, for this customer's full strategy: $6.35M initial investment could unlock $2.15 billion in energy savings over 35 years. Your move - Energy should be a strategic asset, not a monthly liability with compounding interest. Don't let fear or inertia cost you your energy future. Don't wait for capital to appear—choose the model that works for you now. What's keeping your company stuck in the energy debt spiral?

In the East Midlands, a large plastics and packaging manufacturer was grappling with spiralling electricity costs. Producing high volumes of moulded packaging for the food and pharmaceutical industries required heavy duty extrusion machines, moulding presses, and climate-controlled storage areas. By early 2024, monthly energy bills had climbed to £25,000, eating into margins in a sector already under pressure from global competition and fluctuating resin prices. The finance director admitted: “We were running faster just to stand still. Efficiency upgrades gave us small gains, but they couldn’t offset the sheer scale of energy price rises.” During a strategic review, attention turned to the factory’s vast flat roof. It was large enough to accommodate a solar system capable of offsetting the majority of daytime consumption. The sticking point was cost. A system of this size required a six-figure investment that the business was unwilling to tie up, especially given the need for flexibility in raw material purchasing. Asset finance proved to be the game-changer. By structuring the project through a financing plan, the company avoided any upfront capital expense. Instead, the repayments were set below what they were already paying for grid electricity. ‘This meant the project was immediately cash-positive from the first day of generation.’ Installation took less than 12 weeks, with minimal disruption to operations. Once live, the rooftop solar system supplied over 60% of the factory’s electricity needs during production hours. Grid dependence fell sharply, and monthly bills dropped to around £10,000, with finance repayments of just £12,000. The net effect was a saving of £3,000 every month - until the finance was settled - then increasing to £15,000 in monthly savings thereafter. Over 25 years, the company is set to save over £4 million (extra profit), while also avoiding more than 900 tonnes of CO₂ emissions. For a packaging supplier under scrutiny from eco-conscious FMCG and pharmaceutical clients, this sustainability investment has already proven decisive. Shortly after installation, the company won a new long-term contract with a global food brand. The client specifically cited the supplier’s reduced carbon footprint and commitment to renewable energy as part of its supplier selection criteria. The managing director reflected: “Solar didn’t just cut costs. It opened doors. Customers want greener suppliers, and now we can prove we are one.” The benefits have also spilled into recruitment and retention. Employees - particularly younger engineers and designers - have responded positively to the company’s sustainability push, taking pride in working for a business leading the shift towards greener manufacturing. For finance directors in plastics and packaging, the message is clear: ‘Solar is not only a cost-saving measure but a strategic lever for growth.’