Financial Forecasting In Projects

Some investors in renewables made 3–5X returns. Others marked their investments to zero. The only difference? The type of bet they placed. In the last 9 years, renewable energy deals in India went from 134 to 230.  Total investment received - $62 billion But the money investors made when selling? Down 75%. But here's the strange part: some investors are losing money while others are making huge returns. The difference is simple. Two types of investors are playing completely different games: Type 1: Buying working renewable energy projects Think of this like buying a rental property that already has tenants paying rent. ↳ Brookfield paid $1.7 billion for solar and wind farms that are already operating.  ↳ Quebec pension fund paid $7 billion to buy a company that runs renewable energy plants. These farms have contracts to sell electricity at fixed prices for 20-25 years. Predictable money every month. Low excitement, but safe returns. Type 2: Betting on new renewable technology This is like investing in a startup before it makes any money. E-mobility jumped from 6% to 49% of deal volume by 2024. Battery storage grew from 1% to 9%. These sectors are projected to grow 12-35% annually. But they're not profitable yet. They need years to build, test, and scale. ↳ BlackRock marked down its Global Renewable Power Fund III to negative returns. ↳ Riverstone Holdings marked down at least seven investments, some to zero. What went wrong: 📍Startups bought at inflated prices didn't grow fast enough.  📍Government subsidies became uncertain.  📍High interest rates killed exit valuations. The lesson for investors managing significant capital: Mature renewables = lower returns but predictable income. Perfect for pension funds and family offices seeking stability. Emerging sectors = higher risk but 3-5X return potential. Only bet what you can afford to lose. Pick one strategy and stick to it. Which approach makes more sense for you?

An investor nearly walked away from one of our solar deals over a 2% IRR gap. The project was solid, with around 14% IRR, good fundamentals and strong offtake. He had been engaged the whole time, asking the right questions and clearly thinking it through. Then he said he wanted 16, maybe 17% IRR. The first instinct was to go back to the model, adjust a few assumptions, and try to bridge the gap on paper, but we didn't do that. Instead we just asked him what would actually make the deal work for him. Turns out it wasn't really about the IRR. He was more worried about how the cash flows looked in the early years and what his downside looked like if things didn't go as planned. So we adjusted the structure. We introduced a preferred return so he would get paid before us, added a performance upside if the asset did well, and made a small adjustment to his entry price. The model assumptions didn't change, but the way the returns were structured did and that was enough to get the deal done. It made me realize how often the default reaction is to fix the model when an investor pushes back on returns. Sometimes that's not what they're actually asking for. Sometimes it's just about understanding what they're worried about and structuring the deal around that. Have you been in situations where the deal came down to structure rather than economics? What worked? #RenewableEnergy #Fundraising #ProjectFinance #EnergyTransition

💡 Most Important Economic Metrics in Solar PV Projects 1️⃣ Core Financial Performance Metrics • Levelized Cost of Energy (LCOE) - Average cost per kWh generated over the project’s lifetime. - The lower the LCOE, the more competitive the project. • Internal Rate of Return (IRR) - Discount rate that makes NPV = 0 - a key profitability metric for investors. - Utility-scale: 10–14% | C&I: 12–20% | Residential: 18–25%. • Net Present Value (NPV) - Difference between discounted inflows and outflows. - NPV > 0 → the project is financially viable. • Payback Period - Time required to recover initial investment. - Typical PV payback: 4–7 years (C&I) 💰 2️⃣ Cost Structure Metrics • CAPEX (Capital Expenditure) - Modules, inverters, BOS, land, construction. • OPEX (Operating Expenditure) - O&M, cleaning, insurance, admin. • Debt-to-Equity Ratio - Defines your financial leverage — typically 70% debt / 30% equity. • DSCR (Debt Service Coverage Ratio) - Cash available for debt service ÷ total debt service. 3️⃣ Revenue & Production Metrics • Annual Energy Yield (MWh/MWp/year) - Energy produced per installed MWp. • Performance Ratio (PR) - Actual vs. theoretical output efficiency. - Typical: 75–85%. • Capacity Utilization Factor (CUF) - Actual generation ÷ (Installed Capacity × 8760h). - Typical: 18–25%. • Tariff or PPA Price - Defines your revenue - fixed or escalating (1–2%/year common in Africa). • Policy & Market Factors - Local content requirements & incentives - Import tariffs / VAT exemptions - Grid connection costs - Currency & inflation risk - Offtaker creditworthiness - National regulations (e.g., SERA’s self-consumption framework in KSA) 💡 Pro Tip: Mastering these metrics turns a technical project into a bankable investment case.

There is an interesting pattern emerging in many of my recent conversations with investors and IPPs Too many projects are still being underwritten on assumptions that no longer hold due to three specific blind spots that keep coming up: Midday glut exposure: In 2024, Europe recorded nearly 5,000 hours of zero or negative power prices. In 2025 it got worse. Projects optimized for peak solar output aren't just selling into the worst pricing window. In some markets, they're literally paying to deliver power. Missing the morning and evening premium: The highest-value hours on the grid are no longer at noon. They're early morning and late afternoon. Investors not designing for this are leaving revenue on the table from day one. Land cost trajectory: Panel costs have dropped 90% in a decade. Land costs have gone the other way. Projects still designed around cheap, abundant land, with layouts that waste 10-15% of a site's edge and corner capacity, are quietly undermining their own economics before a single panel is installed. None of these kill a project overnight. But they compound. Fast. A few points of IRR lost to midday price exposure, a few more from suboptimal production timing, a few more from inefficient land use. And what looked like a solid return at financial close starts to look very different at year 4. So what are the best investors doing differently? They're not just adjusting a spreadsheet. They're rebuilding the design logic from scratch around three questions: When is power actually valuable in this market? Where on this site can we recover margin that a standard layout leaves behind? How do we build flexibility into the system so it can respond as grid conditions evolve? The result isn't a dramatically different project on paper, but it's a meaningfully different IRR profile over a 25-year hold. Pictured below is a Solargik project avoiding those blindspots... Which of these blind spots are you seeing most in your market?

𝐖𝐡𝐲 𝐔𝐭𝐢𝐥𝐢𝐭𝐲-𝐒𝐜𝐚𝐥𝐞 𝐒𝐨𝐥𝐚𝐫 𝐢𝐧 𝐈𝐧𝐝𝐢𝐚 𝐈𝐬 𝐚 𝐏𝐨𝐰𝐞𝐫𝐟𝐮𝐥 𝐈𝐧𝐯𝐞𝐬𝐭𝐦𝐞𝐧𝐭 — 𝐁𝐚𝐜𝐤𝐞𝐝 𝐛𝐲 𝐑𝐞𝐚𝐥 𝐍𝐮𝐦𝐛𝐞𝐫𝐬 When investors look at renewable energy, the real question isn’t “𝐈𝐬 𝐢𝐭 𝐠𝐫𝐞𝐞𝐧?” It’s “𝐃𝐨𝐞𝐬 𝐢𝐭 𝐩𝐫𝐨𝐭𝐞𝐜𝐭 𝐜𝐚𝐩𝐢𝐭𝐚𝐥, 𝐠𝐞𝐧𝐞𝐫𝐚𝐭𝐞 𝐜𝐚𝐬𝐡, 𝐚𝐧𝐝 𝐨𝐩𝐭𝐢𝐦𝐢𝐬𝐞 𝐭𝐚𝐱𝐞𝐬?” Let’s look at this through an actual 100 MW solar project in India, not theory. 📌 𝐏𝐫𝐨𝐣𝐞𝐜𝐭 𝐒𝐧𝐚𝐩𝐬𝐡𝐨𝐭 (𝐈𝐧𝐝𝐢𝐚) • Capacity: 100 MW utility-scale solar • Total capitalised cost: ₹464 Cr • EPC + performance + land lease + insurance included • Asset life: 25 years • Revenue: Contracted under long-term PPA 💰 𝐓𝐚𝐱 𝐄𝐟𝐟𝐢𝐜𝐢𝐞𝐧𝐜𝐲 (𝐎𝐟𝐭𝐞𝐧 𝐎𝐯𝐞𝐫𝐥𝐨𝐨𝐤𝐞𝐝, 𝐇𝐢𝐠𝐡𝐥𝐲 𝐏𝐨𝐰𝐞𝐫𝐟𝐮𝐥) Under India’s Income-tax Act, solar assets qualify for 40% WDV depreciation every year. What this means in practice: • Year-1 depreciation: ₹185.6 Cr • Year-1 tax saving: ~₹46.7 Cr • Tax saved in first 5 years: ~₹108 Cr • Lifetime tax shield: ~₹116–117 Cr • ~25% of total project cost recovered through tax savings alone 📊 𝐖𝐡𝐚𝐭 𝐭𝐡𝐞 𝐃𝐞𝐩𝐫𝐞𝐜𝐢𝐚𝐭𝐢𝐨𝐧 𝐂𝐮𝐫𝐯𝐞 𝐓𝐞𝐥𝐥𝐬 𝐔𝐬 • ~80% of depreciation benefit is realised in the first 5–6 years • Asset book value drops rapidly, while cash generation continues for 25 years • Solar becomes a tax-efficient infrastructure asset, not just an energy project ⚙️ 𝐎𝐩𝐞𝐫𝐚𝐭𝐢𝐨𝐧𝐚𝐥 𝐑𝐞𝐚𝐥𝐢𝐭𝐲 • Predictable O&M costs • EBITDA stabilises quickly after COD 🧠 𝐖𝐡𝐲 𝐓𝐡𝐢𝐬 𝐌𝐚𝐭𝐭𝐞𝐫𝐬 𝐟𝐨𝐫 𝐈𝐧𝐯𝐞𝐬𝐭𝐨𝐫𝐬 & 𝐂𝐨𝐫𝐩𝐨𝐫𝐚𝐭𝐞𝐬 • Improves post-tax equity returns • Creates a natural hedge against taxable profits • Enables refinancing or exit once asset risk reduces • Attractive to infrastructure funds, utilities, and long-term capital Contact Hardik Sheth for more details.. post sharing for information..

Investing in solar energy is not just about sustainability—it’s about strong financial returns. But what’s considered a good IRR (Internal Rate of Return) for a solar project? ✅ Key IRR Benchmarks: 🔹 8-12% IRR – Common for utility-scale solar projects with long-term PPAs. 🔹 12-18% IRR – Achievable in C&I (Commercial & Industrial) solar, especially with high grid tariffs. 🔹 18-25% IRR – Possible in rooftop solar or CAPEX models, depending on incentives and financing. 🔹 Factors Impacting IRR: ✅ Tariff Rates & PPA Terms – Higher tariffs or favorable PPA terms improve returns. ✅ Capex & Opex Costs – Lower costs = higher profitability. ✅ Subsidies & Tax Benefits – Accelerated depreciation & incentives can boost IRR. ✅ Panel Efficiency & Generation – Better technology ensures higher energy yield. ✅ Financing Terms – Interest rates & loan structures impact returns significantly. 💡 Bottom Line: A good IRR depends on the market, risk appetite, and financing structure. For most investors, above 12% IRR is attractive, but higher is always better!