Obstacles to Developing Bankable Solar Projects

Not every C&I solar project is viable, I learnt this the hard way. It’s easy to jump at the show of a new C&I lead. Many developers and EPCs assume that every working factory, mart, farm, or hospital is a viable solar candidate. You scan industrial rooftops, chase meetings, and finally get invited to perform site assessments and energy audits. Excitement builds. You involve the engineering team, you design diligently, you push hard through your process. But then, weeks or months in, you hit a roadblock: the economics don’t stack, the client can’t commit, or the financier isn’t convinced. C&I projects aren’t about panels and batteries. They’re about business cases. And business cases need to make sense to two groups: The Offtakers → clients who must see real savings and operational value. The Financiers → investors who must see risk-adjusted returns. If you can’t defend both sides, then what you have is not a project, it’s just a lead. So, how do you qualify early? Start with three fundamental filters: 1️⃣ Load Profile: Does the client’s consumption pattern align with solar generation? A factory running 8 am–6 pm is viable. A hotel with peak load at midnight may not be, unless they’re ready to pay for storage. 2️⃣ Tariff Environment: What benchmark are you competing against? If grid tariffs are cheap and reliable, solar won’t make economic sense. But if diesel costs are spiraling, solar PPAs suddenly become compelling. 3️⃣ Client’s Energy Spend & Financial Strength: Is power a material cost for the business (e.g., power costs 20% of OPEX in agro-processing = urgent). And beyond these, you must run feasibility studies. They’re not paperwork. They’re the due diligence backbone: Technical → can the system physically work? Financial → do the numbers hold under stress tests? Legal/regulatory → are there barriers to connect or operate? Operational → will the client maintain and honor commitments? 🚩 Red flags you must not ignore: → Night-heavy loads with no storage appetite. → Clients with poor creditworthiness. → Subsidized tariff environments where solar can’t compete. → Weak roof structures or no space for panels. → Clients treating energy as a “nice to have” rather than a strategic priority. #SolarEnergy #RenewableEnergy #CISolar #EnergyTransition #PPAs #SolarProjects #EnergyFinance #CommercialSolar #IndustrialSolar #ProjectFinance #EnergyManagement #SolarDevelopment

From Design to Bankability: Lessons from Mining PV + BESS Projects in South Africa South Africa’s mining sector is under pressure: rising electricity costs, grid unreliability, and carbon-reduction targets are accelerating the shift to hybrid renewable power. Solar PV combined with battery storage (BESS) is no longer just a technical solution: it’s becoming a strategic necessity. But here’s the catch: the engineering case is strong, yet the real test lies in making these projects bankable for lenders, sponsors, and mining offtakers. From recent mining-linked projects, five lessons stand out: 1️⃣ Availability ≠ Performance Meeting “availability” guarantees isn’t enough. If solar yield is low, DC/AC ratios too high, or battery losses significant, lenders are left exposed. Bankability must focus on delivered output, not just uptime. 2️⃣ Baseload Commitments Demand Hybrid Thinking Mining operations require firm, 24/7 supply. The design focus shifts from maximizing solar yield to storage duration, dispatch strategy, and managing degradation risk. Guarantees must link directly to PPA baseload requirements. 3️⃣ Liquidated Damages Must Match Exposure Mines operate with high daily burn rates. If EPC/O&M LD caps don’t align with PPA penalties, lenders see coverage gaps. Structuring aggregate LDs across PV + BESS is key to comfort and confidence. 4️⃣ Grid Interconnection Cannot Be an Afterthought Remote substations and lines are often left outside EPC scope: but without them, COD slips. Early clarity on ownership, cost, and delivery responsibility is essential. 5️⃣ Degradation and Long-Term O&M PV panels and batteries both degrade. Lenders need credible O&M strategies, retention mechanisms, and step-down LDs to ensure reliable supply throughout the PPA term. ⚖️ Bottom line: For mines, renewables are not just about cheap or clean energy. They’re about certainty: that supply commitments under the PPA will be met for 10, 15, 20 years. Projects that integrate this perspective from day one will be the ones that secure financing and scale.

Three things determine whether a solar project gets built: interconnection, offtake, and capital stack discipline. Everything else is secondary. After years financing first-of-its-kind projects at the DOE and operating distributed solar portfolios at Aligned Solar Partners, these projects fail because one of three pillars breaks. 1. Interconnection The question you must ask yourself is whether you can get on the grid. Right now, hundreds of gigawatts of generation are sitting in interconnection queues - some waiting 5-7 years for grid access. At ASP, we focus on 1-20MW distributed projects specifically because they move through interconnection faster. The bottleneck is real, and your strategy has to account for it. 2. Offtake Who is paying for the electrons, and under what terms? Long-term contracts, typically 20+ years, are what make project finance possible. Municipalities, commercial and industrial buyers, community solar subscribers - these contracted revenue streams are what lenders underwrite against. Without locked offtake, there’s no debt. Without debt, there’s no project. It’s that sequential. 3. Capital stack discipline Tax credits, debt, and equity have to be structured precisely and in the right order. Federal investment tax credits monetize a significant portion of value at construction. Contracted operating income generates annual distributions. A seasoned portfolio of de-risked assets commands premium valuations from institutional buyers. When all three align correctly, the result is strong, risk-adjusted returns across the fund life. Miss any one of these and the project stalls… or never gets financed at all. At its core, solar has become an execution story. Energy systems are physical systems, and the people who understand that interconnection, offtake, and capital stack discipline are the actual variables will be the ones building projects that make it to the grid.

After years navigating the complexities of solar projects, I've distilled my learnings into what I call the 'Triple-P' framework – a North Star for viable and impactful solar development. It’s not just theory; it’s how I’ve personally approached and seen projects thrive, or sometimes stumble. I remember one early project where we had groundbreaking technology, but the local policy landscape was a labyrinth. We spent months untangling permits and understanding incentive structures. That's when 'Policy' became my first P. It’s the bedrock. Without a clear, supportive regulatory environment, even the most innovative project can get stuck in quicksand. Then there's 'People'. My biggest lesson here came from a community solar initiative. We had all the technical specs right, but we hadn't genuinely engaged the local residents from day one. Their concerns, their questions – we hadn't prioritized them. The project faced significant delays until we truly listened, adapting our approach. It highlighted that building trust and fostering local buy-in is as critical as any engineering design. Finally, 'Partnerships'. I’ve seen projects soar when diverse expertise comes to the table – from financiers and developers to local suppliers and community leaders. One particularly successful utility-scale project was a masterclass in collaboration, leveraging unique strengths to overcome challenges that no single entity could have tackled alone. So, before diving into the megawatts and financial models, I always ask: Have we truly understood the Policy? Are the right People engaged and empowered? And have we forged the essential Partnerships? These three pillars, for me, define a project's true potential. What are your non-negotiables when assessing a new energy project? #SolarEnergy #EnergyTransition #ProjectManagement #RenewableEnergy #ThoughtLeadership

Renewable energy projects have a financing problem. Banks won't even talk to them without guaranteed buyers, But here's what's changing the game : A solar farm might generate power for decades, but if there's no committed buyer, lenders see it as too risky. No financing, no project. The renewable energy sits unbuilt. Meanwhile, companies have carbon commitments and need clean electricity. But they can't build their own solar farms or negotiate with every developer independently. Resulting in billions in renewable projects stuck and companies unable to access clean energy. The gap between supply and demand keeps both sides paralyzed. Power Purchase Agreements solve this. A Power Purchase Agreement (PPA) is a long-term contract where a buyer commits to purchasing electricity from a renewable generator at a fixed or indexed price, typically for 10-20 years. Developers get revenue certainty. Banks approve financing. Projects get built. Buyer locks in clean energy at a predictable price plus renewable energy certificates for carbon accounting. Simple mechanism. Massive impact. In 2023, 36 GW of renewable PPAs were signed globally. Corporate PPAs account for over 50% of deals, led by Amazon, Microsoft, and Google. By 2030, corporate PPAs are projected to hit 100 GW. But these barriers kept most companies out: → Long contracts felt risky in unstable markets → Regulations around energy procurement stayed murky → Solar and wind didn't match when companies actually needed power → Small businesses couldn't navigate the complexity Until these startups stepped up: LevelTen Energy tackled price volatility. Largest PPA marketplace connecting 500+ developers with corporate buyers, providing price benchmarks and risk analytics. REDEX solved regulatory complexity. Digital platform helping corporates navigate open access and cross-border clean energy procurement. ReNew addressed generation mismatch. Hybrid solar-wind-storage PPAs aligning with corporate demand, mitigating 4 million tonnes of carbon. Zeigo simplified SME access. Platform making PPA contracting accessible for mid-market companies previously locked out. Clean energy procurement is moving beyond tech giants. Digital marketplaces, standardized contracts, and hybrid PPAs are turning exclusive corporate deals into scalable infrastructure. Projects that couldn't get financed now have buyers. Companies that couldn't access clean energy now have options. Would your company sign a 10-year contract for clean energy if the price was predictable and lower than grid rates? And that's day 9, of Climtober - 31 days demystifying climate solutions, one topic at a time. Come back tomorrow for Day 10 and by November 1st, you'll understand this landscape better than most people working in it. Building climate solutions but struggling to explain why they matter? Check the pinned comment - I help founders turn complex tech into stories that drive real adoption.

What actually makes an energy project “bankable”? It’s rarely the technology. In practice, energy projects fail to reach financing not because the solution doesn’t work, but because the system around it isn’t ready. From experience across gas, clean cooking, and energy-efficiency projects, bankability usually comes down to five fundamentals: 1. Clear regulatory alignment: Financiers need certainty. Licensing, safety standards, tariffs, and approvals must be clearly mapped — not assumed. 2. Predictable revenue streams: Whether it’s LPG distribution, CNG supply, energy-efficiency services, or digital energy platforms, revenue must be structured, measurable, and resilient to shocks. 3. Strong operating model: Banks finance operations, not ideas. Logistics, maintenance, customer management, and risk controls matter as much as the technology itself. 4. Local content and partnerships: Projects with credible local partners move faster, face fewer disruptions, and build long-term trust with regulators and communities. 5. Risk allocation that makes sense: Successful projects don’t eliminate risk — they allocate it realistically across sponsors, operators, financiers, and customers. This is why energy bankability is not created in the boardroom alone. It’s built on the ground through pilots, regulatory engagement, and disciplined execution. As Tanzania accelerates its energy transition — across clean cooking, gas solutions, and energy efficiency — the real opportunity lies in designing projects for bankability from day one. That’s how good ideas become investable projects. #EnergyFinance #EnergyTransition #BankableProjects #CleanCooking #LPG #CNG #EnergyEfficiency #LocalContent #Tanzania #PublicPrivatePartnership

𝐀𝐟𝐫𝐢𝐜𝐚’𝐬 𝐑𝐞𝐧𝐞𝐰𝐚𝐛𝐥𝐞 𝐁𝐨𝐨𝐦 𝐖𝐢𝐥𝐥 𝐃𝐞𝐩𝐞𝐧𝐝 𝐨𝐧 𝐎𝐧𝐞 𝐓𝐡𝐢𝐧𝐠: 𝐁𝐚𝐧𝐤𝐚𝐛𝐥𝐞, 𝐄𝐂𝐀‑𝐁𝐚𝐜𝐤𝐞𝐝 𝐒𝐭𝐫𝐮𝐜𝐭𝐮𝐫𝐞𝐬 Every year, reports such as the Africa Solar Outlook 2026 (link for the report below) remind us of the same paradox: there is no shortage of capital for African renewables, but there is a shortage of projects that global capital can actually finance. The real bottleneck isn’t need or enthusiasm. It is structure. Across the continent, developers are wrestling with the same challenges:   - Hard‑currency debt vs. local‑currency revenues   - Sovereign credit constraints   - EPC and supply‑chain risk   - Limited appetite for long tenors from commercial lenders  This is exactly where Export Credit Agencies (ECAs) are quietly reshaping the landscape. ECA-backed structures are becoming the backbone of serious renewable deployment in Africa because they do three things exceptionally well:   1. Derisk early-stage development, giving investors confidence to commit.   2. Provide long-tenor, competitively priced debt, which dramatically improves project economics.   3. Crowd in commercial banks and DFIs, creating financing stacks that actually close. In my experience leading and structuring renewable energy portfolios, the projects that move from PowerPoint to COD are the ones that combine strong local execution with smartly engineered ECA-backed finance. Africa doesn’t need more optimism. It needs bankable structures, pragmatic risk allocation, and developers who understand how to navigate both the commercial and political realities of the continent. If you’re exploring solar, wind, hydro, hybrid, or storage projects in Africa, or if you’re evaluating how to structure equity and debt to make your pipeline truly financeable. I’m always open to a conversation. This is the moment to build.  But only the well-structured projects will get funded. 𝐋𝐞𝐭’𝐬 𝐭𝐚𝐥𝐤. Link for the report Africa Solar Outlook 2026 issued today: https://lnkd.in/ed8P3FJN

The biggest bottleneck in India’s $500 billion renewable opportunity is not energy. It is land. India’s renewable energy journey in 2026 has reached a defining inflection point. As of April 2026, the country has surpassed 274 GW of total renewable capacity, including nearly 150 GW of solar. In March 2026 alone, India added a record 6.6 GW of solar capacity. On the surface, this signals strong momentum. But beneath this growth lies a structural constraint that is beginning to reshape the entire sector. The Supreme Court’s conservation framework around the Great Indian Bustard has significantly altered development in Rajasthan and Gujarat, India’s most resource-rich renewable states. Under revised priority areas, no new solar plants above 2 MW and no new wind turbines are permitted. Transmission infrastructure must also be undergrounded or rerouted, increasing capital costs and delaying the Green Energy Corridor. At the ground level, developers are struggling to secure large, contiguous, litigation-free land parcels. Fragmented ownership, unclear titles, and legacy land records are slowing down execution. Even after land is secured, right-of-way challenges for transmission lines are extending timelines by 12 to 18 months, often longer than plant construction itself. Economic pressures are intensifying this challenge. Land near substations is scarce and expensive. Moving to cheaper, remote land increases evacuation costs, reducing project viability. As a result, many projects are now witnessing cost overruns of 10 to 15 percent. What is striking is that India has utilized only about 4 percent of its 3,343 GW ground-mounted solar potential. Achieving a 90 percent renewable grid would require just 6.7 percent of suitable wasteland, less than 1 percent of total land area. The issue is not land availability. It is execution-ready land. For every 1 GW of demand, the system now requires approximately 4.9 GW of solar along with 13.5 GWh of battery storage. Hybrid energy models integrating solar, wind, and storage are becoming the new standard, maximizing output from limited land. At the same time, new models are emerging. Solar parks with plug-and-play infrastructure, Agri-PV under PM KUSUM, floating solar with a 300 GW potential, and rapidly scaling rooftop solar are reshaping how India approaches this challenge. The opportunity, however, is massive. India does not lack land. It lacks litigation-free, contiguous, infrastructure-ready land. Land banking is no longer passive. It is becoming a strategic renewable infrastructure play. Those who can aggregate land, de-risk it, secure connectivity, and align capital will define the next decade. For private equity, especially from UAE and Indian HNI investors, this represents a high-conviction entry point into India’s energy transition. How are you navigating land and transmission bottlenecks in your projects? #SunilMall #RenewableEnergy #EnergyTransition

The first draft of the Power Purchase Agreement was completely unbankable. That's more common than you might think. Many developing countries publish a template PPA for renewable energy projects. On paper, this looks efficient. In practice, those templates often fall far short of what’s needed to raise finance. The types of issues we see include: - A buyer with poor credit and no government guarantee - Developers forced to take grid and curtailment risks - Limited protection if the law or regulations change - Weak remedies on termination or political force majeure - Uncertainty around currency convertibility and offshore transfers - Lack of clear arbitration mechanism to resolve disputes - Term too short to repay the financing On those terms, it's impossible for an international lender to finance the project. As legal advisors, this is where we add value. We analyse risk allocation and negotiate the PPA into a version that lenders will actually accept. Fun(?) fact: I once spent 8 years negotiating a PPA with a state-owned power company. The PPA is the foundation for the entire financing. Get it right and everybody wins. Get it wrong and the project never gets built. 👉 I'm Kristian. I help sponsors, investors, and lenders get global energy, infrastructure and tech transactions structured and closed. Follow for insights - and let's connect. [Photo by Carolien van Oijen on Unsplash, with author's edits]

𝐇𝐢𝐝𝐝𝐞𝐧 𝐑𝐢𝐬𝐤𝐬 𝐢𝐧 𝐚 𝟏𝟎𝟎𝐌𝐖 𝐒𝐨𝐥𝐚𝐫 𝐏𝐫𝐨𝐣𝐞𝐜𝐭 𝐄𝐯𝐞𝐫𝐲 𝐈𝐧𝐯𝐞𝐬𝐭𝐨𝐫 𝐒𝐡𝐨𝐮𝐥𝐝 𝐊𝐧𝐨𝐰. When we look at a 100MW utility-scale solar project, most discussions focus on: • CAPEX • module pricing • financing cost • LCOE But in reality, several 𝐥𝐞𝐬𝐬 𝐯𝐢𝐬𝐢𝐛𝐥𝐞 𝐫𝐢𝐬𝐤𝐬 can materially change project economics. Let’s consider a typical project assumption: • Capacity: 100MW • Total CAPEX: ~$95M • Annual generation: ~175,000 MWh • Project life: 25 years Even small operational or infrastructure surprises can shift the economics. 𝐅𝐨𝐫 𝐞𝐱𝐚𝐦𝐩𝐥𝐞: • Interconnection upgrades can add $2M–$15M in unexpected CAPEX • Curtailment risk can reduce generation by 2–5% annually • O&M escalation typically increases costs by 2–3% every year • Transformer failures without backup can cause months of revenue loss These factors may increase project cost by: ➡ $𝟓𝐌–$𝟏𝟎𝐌 𝐢𝐧 𝐚𝐝𝐝𝐢𝐭𝐢𝐨𝐧𝐚𝐥 𝐜𝐚𝐩𝐢𝐭𝐚𝐥 𝐞𝐱𝐩𝐨𝐬𝐮𝐫𝐞 ➡ $𝟏–𝟑/𝐌𝐖𝐡 𝐢𝐧𝐜𝐫𝐞𝐚𝐬𝐞 𝐢𝐧 𝐋𝐂𝐎𝐄 ➡ 𝐒𝐞𝐯𝐞𝐫𝐚𝐥 𝐦𝐨𝐧𝐭𝐡𝐬 𝐨𝐟 𝐩𝐨𝐭𝐞𝐧𝐭𝐢𝐚𝐥 𝐩𝐫𝐨𝐣𝐞𝐜𝐭 𝐝𝐞𝐥𝐚𝐲 That’s why experienced developers and IPPs spend significant time managing grid, operational, and execution risks, not just equipment pricing. 𝐊𝐞𝐲 𝐓𝐚𝐤𝐞𝐚𝐰𝐚𝐲𝐬 𝐟𝐨𝐫 𝐈𝐧𝐯𝐞𝐬𝐭𝐨𝐫𝐬 𝐚𝐧𝐝 𝐈𝐏𝐏𝐬 • Grid interconnection risk is often the largest unknown early in development • Curtailment risk directly impacts long-term revenue • Supply chain delays can push COD and affect project IRR • O&M escalation compounds over a 25-year asset life • Infrastructure reliability (transformers, SCADA, etc.) protects revenue stability In utility-scale renewables, project economics are not only built in spreadsheets — they are shaped by execution risk management. Understanding these hidden factors early can make the difference between a bankable asset and a marginal one. Visit 👉 https://alendei.energy/ or connect with us for solar and Bess EPC, investment and IPP. #IPP #UtilityScaleSolar #TataPowerRenewables #Suzlon #JSWEnergy #NTPC #SECI #LarsenAndToubro #ACWAPower #Masdar #DEWA #EWEC #NEOM #AmeaPower #AlFanar #CEPCO #SaudiEnergy #UAEEnergy #LekelaPower #Globeleq #AfreximBank #KenGen #Eskom #ZESCO #AfricaIPP #NextEra #Invenergy #PatternEnergy #Enbridge #BrookfieldRenewables #AES #EDFrenewables #HydroOne #DominionEnergy #TCenergy #Vestas #SiemensGamesa #GErenewables #Nordex #CanadianSolar #NextEraEnergy #AESCorporation #NRG #DukeEnergy #Exelon #AlgonquinPower #OntarioPowerGeneration #EDPRenewables #ShellRenewables #BPAlternativeEnergy #ClearwayEnergy #ApexCleanEnergy #ArrayTechnologies #Nextracker #FluorEnergy #BechtelEPC #BlackAndVeatch #BurnsAndMcDonnell #RESAmericas #VestasAmericas #NordexAcciona #SungrowAmerica #TeslaEnergy #LGenergySolution #EatonEnergy #ABBPowerGrids #OmegaEnergia #AtlasRenewableEnergy #Neoenergia #Energisa #CPFLenergia #AesBrasil #AccionaEnergia