Interview: Practitioners on Renewables innovation — what they wish they knew earlier

Global renewable energy capacity additions reached 510 GW in 2024, a 50% increase over the previous year, yet the International Renewable Energy Agency estimates that annual additions must reach 1,000 GW by 2030 to align with the 1.5-degree Celsius pathway (IRENA, 2025). In emerging markets, where electricity demand is growing fastest, renewables accounted for less than 35% of new capacity additions in 2024 compared to over 75% in OECD nations. Product and design teams working on next-generation solar, wind, and geothermal technologies face unique challenges spanning grid integration, supply chain localization, and regulatory fragmentation across fast-growing economies. Seven practitioners shared what they wish they had understood before deploying renewable energy innovations in markets from Sub-Saharan Africa to Southeast Asia.

Why It Matters

Emerging markets will account for over 80% of global electricity demand growth through 2040, yet these regions receive less than 15% of global clean energy investment (BloombergNEF, 2025). The gap between technology readiness and deployment readiness is particularly acute: perovskite-silicon tandem solar cells achieved 33.9% laboratory efficiency in 2025, next-generation wind turbines exceed 15 MW nameplate capacity, and enhanced geothermal systems have demonstrated commercial viability in multiple geologies. But translating laboratory breakthroughs and proven technology from developed markets into bankable projects in emerging economies requires navigating currency risk, off-taker creditworthiness concerns, land tenure complexity, and grid infrastructure limitations that product teams rarely encounter during initial R&D cycles.

The financial implications are significant. The levelized cost of electricity from utility-scale solar PV fell below $30 per MWh globally in 2025, yet project-specific costs in Sub-Saharan Africa average $45 to $65 per MWh due to higher financing costs, import duties on equipment, and limited local installation capacity (IRENA, 2025). For wind energy, the cost differential between Northern Europe and Southeast Asia ranges from 40% to 70% on a per-MWh basis, driven primarily by financing spreads rather than technology costs. Product teams designing for these markets must understand that technology performance is often secondary to project economics, regulatory certainty, and local stakeholder alignment.

Key Concepts

Several foundational concepts shape the renewables innovation landscape in emerging markets.

Perovskite-Silicon Tandem Cells: Next-generation photovoltaic technology that layers a perovskite absorber on top of a conventional silicon cell, theoretically capable of exceeding 43% efficiency. Oxford PV began commercial shipments of tandem cells in 2025, achieving 26.8% module-level efficiency, representing a 20% improvement over standard PERC silicon modules.

Enhanced Geothermal Systems (EGS): Technology that creates artificial geothermal reservoirs by injecting fluid into hot dry rock formations, expanding geothermal energy potential beyond naturally occurring hydrothermal resources. Fervo Energy's Project Red in Utah demonstrated 3.5 MW of continuous power output from its first commercial EGS well pair in 2024.

Floating Offshore Wind: Wind turbines mounted on floating platforms anchored to the seabed, enabling deployment in water depths exceeding 60 meters where fixed-bottom foundations are not feasible. Hywind Tampen in Norway, operational since 2023, is the world's largest floating wind farm at 88 MW and has achieved capacity factors above 50%.

Bankability: The assessment by lenders and investors that a project has sufficient technical maturity, contractual certainty, and risk mitigation to justify non-recourse project financing. In emerging markets, bankability often requires sovereign guarantees, political risk insurance, or concessional debt layers that add 12 to 24 months to financial close timelines.

Grid Curtailment: The forced reduction of renewable energy output due to grid congestion, transmission constraints, or oversupply conditions. China curtailed approximately 40 TWh of wind and solar generation in 2024, representing an estimated $2.8 billion in lost revenue for developers (China National Energy Administration, 2025).

What's Working

Practitioners identified approaches that consistently deliver results across emerging market deployments.

Modular system architectures designed for incremental scaling are outperforming large monolithic projects in markets with uncertain demand forecasts. In Nigeria, Husk Power Systems has deployed over 200 mini-grid systems using containerized solar-plus-storage units that can be expanded in 50 kW increments as local demand grows. The company's product team learned that designing for 30% initial utilization with clear upgrade pathways produced better financial returns than sizing systems for projected peak demand, because demand forecasts in rural emerging markets routinely overestimate growth by 40 to 60% in the first three years.

Local manufacturing partnerships are proving critical for cost reduction and regulatory compliance. Trina Solar's partnership with Risen Energy to establish module assembly capacity in India reduced landed costs by 22% compared to imports from China after accounting for India's 40% basic customs duty on imported solar modules (Ministry of New and Renewable Energy, India, 2025). More importantly, local assembly created a service and warranty infrastructure that reduced post-installation defect resolution times from 45 days to under 10 days, directly improving project bankability in the eyes of local lenders.

Hybrid renewable configurations that combine multiple generation sources with storage are solving grid integration challenges that stalled earlier single-technology projects. In Kenya, Lake Turkana Wind Power (310 MW) initially faced curtailment rates exceeding 15% due to transmission constraints. When the developer added a 40 MWh battery energy storage system in 2024, curtailment dropped below 4%, and the project began providing ancillary services to Kenya Power that generated an additional $3.2 million in annual revenue. Product teams now design integrated generation-storage solutions from the outset rather than treating storage as an aftermarket addition.

Standardized power purchase agreement templates developed by organizations like the International Finance Corporation have reduced legal negotiation timelines from 14 to 18 months to 4 to 6 months in markets including Zambia, Senegal, and Vietnam. Practitioners emphasized that template adoption is not merely a legal convenience but a bankability accelerator, because lenders can underwrite familiar contract structures faster and with lower due diligence costs.

What's Not Working

Practitioners were equally forthcoming about persistent failures and structural challenges.

Technology transfer without local engineering capacity development has produced maintenance crises across multiple markets. A 100 MW wind farm in Ethiopia equipped with European turbines experienced availability rates below 70% in its third year of operation because the original equipment manufacturer had no permanent service presence in the country. Replacement parts required 8 to 12 weeks for delivery from Europe, and locally trained technicians lacked authorization to perform critical maintenance tasks. The developer estimated $14 million in foregone revenue over three years due to extended downtime.

Currency devaluation risk continues to undermine project economics in ways that product and design teams rarely anticipate during technology development. In Egypt, the pound lost approximately 50% of its value against the US dollar between 2022 and 2024. Solar developers with dollar-denominated equipment costs and local-currency power purchase agreements saw effective project returns decline by 8 to 12 percentage points, rendering several projects financially unviable despite excellent technical performance. Practitioners stressed that currency hedging must be embedded in product pricing models and project financial structures from inception rather than treated as a treasury function.

Grid infrastructure limitations in emerging markets frequently make the cheapest renewable technology the wrong choice. In parts of Indonesia, developers installed large utility-scale solar farms only to discover that local distribution networks could not absorb more than 30% variable generation without voltage stability issues. Retrofitting grid infrastructure added $0.02 to $0.04 per kWh to effective project costs, erasing the cost advantage over gas-fired generation. Practitioners who conducted grid hosting capacity studies before site selection avoided this trap, but the studies themselves cost $200,000 to $500,000 and required 6 to 9 months to complete.

Community engagement failures have delayed or cancelled projects despite strong technical and financial fundamentals. A geothermal project in Tanzania encountered multi-year delays after local communities raised concerns about water table impacts and sacred site proximity that the developer had not identified during initial environmental impact assessments. The developer eventually redesigned the wellfield layout at a cost of $8 million, adding 30 months to the project timeline.

Key Players

Established Companies

• Vestas: World's largest wind turbine manufacturer with over 188 GW installed globally, operating service centers across 40 emerging market countries
• JinkoSolar: Leading solar module manufacturer shipping 75 GW in 2024, with manufacturing presence in Malaysia, Vietnam, and the United States
• Orsted: Danish energy company that pioneered offshore wind development in Europe and is expanding into markets including Taiwan, South Korea, and Vietnam
• Enel Green Power: Subsidiary of Enel with 63 GW of renewable capacity across 28 countries, strong presence in Latin America and Africa
• Siemens Gamesa: Wind turbine OEM with dedicated product lines for low and medium wind speed sites common in emerging markets

Startups and Innovators

• Oxford PV: UK-based developer commercializing perovskite-silicon tandem solar cells with 26.8% module efficiency
• Fervo Energy: US geothermal company deploying enhanced geothermal systems using horizontal drilling techniques adapted from the oil and gas industry
• Husk Power Systems: Distributed energy company operating over 200 solar-plus-storage mini-grids across India and Sub-Saharan Africa
• Sun King (formerly Greenlight Planet): Off-grid solar company that has sold over 100 million solar products across 65 countries

Investors and Funders

• International Finance Corporation (IFC): World Bank Group member that deployed $4.4 billion in climate finance in fiscal year 2024, with dedicated programs for emerging market renewables
• Africa Finance Corporation (AFC): Pan-African multilateral institution investing in renewable energy infrastructure across the continent
• Actis: Private equity firm with over $6 billion invested in emerging market energy infrastructure across Latin America, Africa, and Asia

Action Checklist

• Conduct grid hosting capacity assessments at potential deployment sites before finalizing technology selection to avoid costly grid reinforcement requirements
• Evaluate local manufacturing or assembly partnerships to reduce import duty exposure and build in-market service infrastructure
• Design modular system architectures that allow incremental capacity expansion as local demand materializes rather than sizing for peak projected load
• Embed currency risk mitigation into project financial models from inception, including hard-currency PPA provisions or hedging instruments
• Negotiate O&M contracts that include permanent local technician presence and pre-positioned spare parts inventory within the country of deployment
• Adopt standardized PPA templates from IFC or regional development banks to accelerate lender due diligence and financial close
• Engage community stakeholders during pre-feasibility studies, not after environmental impact assessments are complete, to identify social risks early
• Build hybrid generation-storage configurations into initial project designs rather than adding storage as a retrofit

FAQ

Q: How should product teams prioritize between perovskite-silicon tandem cells and conventional silicon for emerging market deployments? A: Conventional monocrystalline PERC and TOPCon silicon modules remain the bankable choice for utility-scale projects in emerging markets through at least 2028. Perovskite-silicon tandems offer superior efficiency but lack the 25-year field reliability data that project lenders require for non-recourse financing. Product teams should begin pilot installations of tandem modules in 2026 to 2027 to accumulate field performance data in tropical and high-humidity environments, where perovskite degradation mechanisms differ from laboratory conditions. Plan for commercial adoption in emerging markets from 2029 onward as bankability evidence matures.

Q: What financing structures work best for renewables in high-risk emerging markets? A: Blended finance structures that combine concessional debt from development finance institutions with commercial equity have proven most effective. The typical structure uses a 60/40 debt-to-equity ratio with the concessional tranche (often from IFC, AfDB, or bilateral agencies) providing below-market interest rates on 40 to 50% of the debt, reducing the weighted average cost of capital by 200 to 400 basis points. Political risk insurance from MIGA or national export credit agencies covers currency transfer restrictions and expropriation risk. For smaller projects below $20 million, aggregation facilities that bundle multiple projects into a single financing vehicle have improved access to institutional capital.

Q: How do practitioners manage the tension between rapid deployment and long-term technology risk? A: Successful practitioners separate the deployment decision from the technology bet. They deploy commercially proven technology (standard silicon PV, onshore wind with established turbine platforms) for revenue-generating projects while running parallel pilot programs with next-generation technology (tandem cells, floating wind, EGS) under dedicated R&D budgets. This approach avoids burdening commercial projects with unproven technology risk while building the performance data needed to transition to next-generation solutions. The typical technology qualification cycle from pilot to bankable deployment takes 3 to 5 years in emerging markets, compared to 18 to 24 months in OECD markets, due to additional lender scrutiny and limited local technical reference projects.

Q: What is the most common mistake product teams make when entering emerging markets? A: Designing for technical performance metrics that matter in developed markets but are irrelevant in the deployment context. Product teams optimize for peak efficiency, rated capacity, and maximum energy yield, while emerging market success depends on system availability, maintainability with local labor, tolerance of power quality fluctuations, and resilience to environmental conditions (dust, humidity, voltage instability) that rarely appear in standard product specifications. One practitioner described shipping advanced inverters to West Africa that required stable grid frequency within 0.5 Hz to operate, when local grid frequency deviations routinely exceeded 2.0 Hz, rendering the equipment unusable without expensive power conditioning equipment.

Sources

• International Renewable Energy Agency. (2025). Renewable Energy Statistics 2025: Global Capacity and Investment Trends. Abu Dhabi: IRENA.
• BloombergNEF. (2025). Energy Transition Investment Trends: Emerging Market Analysis. London: Bloomberg Finance L.P.
• China National Energy Administration. (2025). Annual Report on Renewable Energy Curtailment and Grid Integration. Beijing: NEA.
• International Finance Corporation. (2025). Scaling Solar and Wind in Emerging Markets: Lessons from 10 Years of Project Development. Washington, DC: IFC.
• Ministry of New and Renewable Energy, Government of India. (2025). Annual Report 2024-25: Solar Manufacturing Capacity and Import Policy Update. New Delhi: MNRE.
• DNV. (2025). Energy Transition Outlook: Renewables Technology Cost and Performance Benchmarks. Hovik, Norway: DNV AS.