India’s Solar PV Growth: Capacity Hits 168.04 GW by 2026 solarquarter.com
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Ukraine added up to 1.1 GW of new solar capacity during the first half of 2026, according to preliminary assessments undertaken by the Solar Energy Association of Ukraine (SEAU).
SEAU estimates Ukraine’s total installed solar capacity reached 9.4 GW to 9.7 GW by mid-2026. The association is expecting this year’s additions to reach around 2 GW by the year’s end, growing on the approximately 800 MW in 2024 and 1.5 GW in 2025.
The association explains that much of this year’s growth comes from smaller projects. “We estimate that installations of up to 1 MW, primarily intended for self-consumption, will account for around 80% of new installations in 2026 by number, rather than by capacity,” SEAU’s analysis explains.
SEAU Chairman of the Board Vladyslav Sokolovskyi told pv magazine that distributed generation and energy storage have become essential to Ukraine’s energy security and resilience.
“Their development supports the energy transition while addressing an immediate need: keeping businesses, households and critical infrastructure supplied with electricity during wartime,” he explained.
Sokolovskyi
explained that storage systems offer a reliable source of backup power for households and businesses. He added that for businesses, the economic value of a battery also includes the losses avoided by maintaining essential operations.
Lower equipment costs have also made solar-plus-storage systems more accessible, Sokolovskyi
continued, while batteries can increase solar self-consumption and reduce electricity costs for users.
Ukrainian market data supplied by SEAU put Ukraine’s new battery storage capacity at 2.9 GWh in 2025, making it the fourth largest European market last year. Sokolovskyi
noted the figure covers multiple market segments, including portable battery systems widely used for backup power in Ukraine.
SEAU’s preliminary estimate for storage additions in the first half of 2026 is between 1.6 GWh and 1.9 GWh. Its indicative full-year outlook is around 3.2 GWh.
“Our 2026 outlook for both solar and storage remains conditional on security, access to financing and grid connections,” Sokolovskyi told pv magazine. “Forecasting deployment through the end of 2027 is particularly difficult under current conditions.”
Sokolovskyi
added that restoring capacity lost at the hands of Russian attacks and occupation must go hand in hand with developing distributed generation closer to consumers and enabling critical facilities to operate during interruptions to the external power supply.
“Ukrainian energy experts estimate that the power system needs around 10 GW of new and restored generating capacity across different technologies,” he said. “Generation shortages and damage to electricity networks have contributed to recurring outages and increased reliance on electricity imports from neighbouring EU countries.”
Sokolovskyi
pointed to seven priorities that should guide the next stage of development in Ukraine’s solar and storage markets.
His list of priorities includes rapid restoration and protection of energy infrastructure, continued support for distributed generation, effective insurance and guarantee mechanisms to reduce war-related investment risks and simpler, more predictable grid connection procedures.
The list is rounded out by deeper integration with the EU electricity market, more accessible concessional financing for energy projects and the development of microgrids combining solar and storage with other energy sources where needed.
“Ukraine’s private sector is already investing in new energy capacity despite the war. The next task is to make it easier for that investment to scale through predictable procedures, accessible finance and practical risk-sharing mechanisms,” Sokolovskyi concluded.
“Solar generation and battery storage can play a central role in this effort, helping build a more resilient and flexible power system while meeting consumers’ immediate energy needs.”
Ukraine updated its solar feed-in tariffs earlier this year and more recently, introduced time windows for eligiblity.
Later this week, Ukraine’s state-owned JSC Guaranteed Buyer, the offtaker and intermediary in the country’s electricity market, is running two solar auctions offering a combined 150 MW.
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Advanced materials company Lava Blue has commissioned a 250 kW / 1.45 MWh sodium-sulphur (NAS) battery energy storage system at its Centre for Predictive Research into Specialty Materials (PRiSM) facility in Brisbane’s southeast, marking the first time the technology has been connected to the National Electricity Market (NEM).
The battery, manufactured by Japan’s NGK, has been integrated with 200 kW of existing solar generation at the site and plugged into Energex’s local distribution grid.
Lava Blue said the solar and battery system can supply up to 100% of PRiSM’s peak operating load, supporting the processing of critical minerals into high-purity materials used across battery, semiconductor and advanced manufacturing supply chains.
The project was delivered through the Queensland University of Technology’s (QUT) Queensland Energy Storage Technology (QUEST) Hub, a state government-funded initiative focused on accelerating the development and commercialisation of battery materials, chemistries and systems.
Lava Blue Managing Director Michael McCann said the project provides a real-world demonstration of NAS battery technology, showcasing its potential to support long-duration energy storage for powering commercial and industrial applications as well as supporting grid reliability.
“PRiSM was established to bridge the gap between laboratory research and industrial-scale materials processing, so it is an ideal environment in which to demonstrate a long-duration battery technology under genuine operating conditions,” he said.
“Our advanced materials processes include high-temperature and other energy-intensive operations. Integrating solar generation with long-duration storage gives us the ability to supply those loads with renewable energy for extended periods and better understand how advanced manufacturing can operate alongside future energy systems.”
Lithium-ion technology currently dominates the battery market but it has limits, typically offering short-duration energy storage of just two to four hours. NAS batteries are capable of discharging for six hours or more at rated capacity, making the technology suited to applications including renewable energy firming, peak demand management and grid stability.
Lava Blue said the technology has more than 20 years of commercial operating experience internationally, with approximately 5 GWh deployed across more than 250 applications.
Australia’s first NAS battery system was rolled out in 2023 as part of a microgrid at a Western Australian mining site while Queensland electricity generator CleanCo has previously announced plans to pilot the technology.
QUEST Hub Director Joshua Watts said the PRiSM installation extends that work into a grid-connected industrial setting, providing further operating experience to inform potential future deployment of NAS technology in Australia.
“The successful commissioning of Australia’s first grid-connected NAS battery energy storage system marks an important milestone,” he said. “The project has brought together researchers, industry and government to demonstrate an alternative long-duration energy storage technology under real industrial operating conditions.”
Victoria-based Allset Energy provided the electrical engineering, installation and system integration for the project, including development of the interface between the NAS battery, PRiSM’s solar generation, the facility and the grid.
Queensland manufacturer Advanced Converter Solutions (ACS) designed and supplied the bidirectional DC-DC converter platform that enabled the battery system to integrate with the project’s high-voltage DC infrastructure. More than 80% of the purpose-built control unit was manufactured using Australian content.
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Workers monitor operations in the control room of a photovoltaic power station operated by Huadian (Beijing) New Energy Development Co. Ltd. in Beijing, Wednesday, Sept. 23, 2026.
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Columbia University researchers address false claims about solar, wind, electric vehicles, and battery storage
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Despite the growth in renewable energy adoption, misinformation and disinformation about these technologies persist. That prompted the Sabin Center for Climate Change Law at Columbia University to release a report debunking 38 false claims about solar, wind, electric vehicles, and battery storage.
Notably for farmers and rural areas, this report highlights the multitude of ways in which solar energy will be beneficial to these communities. Agrivoltaics, for example, has been shown to enhance agricultural production and can increase the economic value of the average farm by over 30%. Additionally, farmland could be used more efficiently, as tens of millions of acres of farmland are currently being used to produce corn ethanol. Utility-scale solar produces approximately 31 times more energy than corn-ethanol crops.
The report continues to disprove notions that solar energy is harmful to the environment and biodiversity. Through careful implementation of solar development, negative impacts on biodiversity can be mitigated, and in some instances, can produce benefits to local biodiversity. Furthermore, there is a surplus of evidence showing that the lifecycle emissions of solar energy generation are far lower than fossil fuel generation.
“The positive environmental impacts of solar energy are invaluable,” said Johanna Neumann, Senior Director of the Campaign for 100% Renewable Energy at Environment America Research & Policy Center. “Investing in clean energy to improve public health and combat climate change is worth it.”
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Oswal Pumps Ltd has secured an order from the Telangana Renewable Energy Development Corp. Ltd (TGREDCO) for the deployment of an aggregate rooftop solar capacity of 46.7 MW across 9,937 government schools in 33 districts of Telangana.
The order covers the design, supply, installation and commissioning of 2 kW, 5 kW and 10 kW on-grid solar rooftop PV power plants across the government schools. Oswal will deploy mono PERC/TOPCon solar modules, along with normal structures and RMS, and provide comprehensive maintenance for a period of five years.
The total quoted value stands at INR 273.19 crore, excluding GST.
The project is expected to support the adoption of renewable energy infrastructure across educational institutions in Telangana while contributing to the state’s broader clean energy objectives.
“This marks our first major order from Telangana and an important milestone in expanding Oswal Pumps’ presence into new markets. Being selected as the successful bidder for a programme of this scale underscores the strength of our technical and execution capabilities,” said Vivek Gupta, chairman and managing director, Oswal Pumps Ltd. “We remain committed to delivering this project with a strong focus on quality, timely delivery and long[1]term performance, and look forward to establishing a presence in Telangana while contributing to the State’s clean energy goals.”
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Made in Jackson, WyomingThe facility, located in the Gobi Desert, stores energy using molten salt rather than lithium-ion batteries.
China has commissioned one of the world’s largest hybrid solar power plants, a facility in the Gobi Desert that can continue generating electricity for several hours after sunset. The project combines conventional photovoltaic panels with concentrated solar power (CSP) technology and uses molten salt to store the heat produced during periods of peak solar radiation.
The plant is located in Xinjiang, northwestern China, near the Tian Shan Mountains, in an area of the Gobi Desert with abundant solar radiation. The project is being developed by China Three Gorges Corporation, a state-owned Chinese company specializing in renewable energy generation and known for its involvement in the development of the massive Three Gorges hydroelectric power plant.
The facility has a total capacity of 1,000 megawatts (MW). Of that capacity, 900 MW comes from conventional photovoltaic panels, which generate electricity directly during daylight hours. The remaining 100 MW comes from a concentrated solar thermal generation system designed to store energy as heat and continue producing electricity after direct sunlight is no longer available.
The plant is expected to generate approximately 2.07 terawatt-hours (TWh) of electricity per year, enough to cover the consumption of hundreds of thousands of households. Combining photovoltaic generation with thermal energy storage also allows the plant to adjust its output to meet grid demand and reduce reliance on solar generation exclusively during daylight hours.
One of the system’s key features is that it does not use lithium-ion batteries to store energy. Instead, it relies on thermal energy storage using molten salt. This technology eliminates the need for materials such as lithium and cobalt and also experiences less degradation in the storage system over time.
During the day, the system operates using two different technologies. On one side, photovoltaic panels directly convert sunlight into electricity that can be sent to the grid. On the other, an area of approximately 8.6 million square feet is covered by about 260,000 mirrors that track the sun’s path and concentrate solar radiation onto specialized receivers.
The concentrated solar energy heats a molten-salt system, typically made from a mixture of sodium nitrate and potassium nitrate. These salts can reach temperatures of several hundred degrees and allow the captured energy to be stored for hours while sunlight is available. Instead of storing electricity in batteries, the system retains the heat and uses it later to generate electricity.
Once night falls, the hot molten salt stored in large insulated tanks passes through a heat exchanger. There, it transfers its thermal energy to water, turning it into high-pressure steam. The steam drives a turbine connected to an electric generator, using a process similar to that found in conventional thermal power plants. As a result, the facility can continue generating electricity even after the photovoltaic panels stop receiving sunlight.
After releasing some of its thermal energy, the molten salt cools and is transferred to another tank. The system keeps the salt in liquid form so it can be heated again the following day and the process can be repeated. Its storage capacity allows electricity generation to continue through the night, although nighttime output is lower than the level the facility can reach during periods of peak solar radiation.
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ACEN Corp. said in a Sept. 18 disclosure to the Philippine Stock Exchange that its subsidiaries have given up solar energy operating contracts for projects in Quezon and Zambales provinces.
Abagat Energy Corp. relinquished its contract for a site in Pagbilao, Quezon, on Sept. 11 because of “significant land acquisition challenges affecting the project site.” SolarAce2 Energy Corp. relinquished its contract for Botolan, Zambales, on Sept. 17, citing site-access constraints.
The Philippine Department of Energy awarded the Pagbilao contract in August 2024 and the Botolan contract in June 2021. Its list of awarded solar projects, current to Dec. 31, 2025, puts their potential capacity at 336 MW and 120.30 MW, respectively, with both still in development.
ACEN said the cancellations have no material effect on its operations, as neither project had reached a final investment decision or begun commercial operations.
The department terminated 84 renewable energy contracts in 2025, representing about 5,372 MW of potential capacity, over failures to meet work-program requirements, auction terms, and other department standards. It said in December 2025 that a further 42 projects were under review and warned that noncompliant developers could face blacklisting and forfeiture of performance bonds.
ACEN reported about 7.5 GW of attributable renewable capacity, including capacity under construction, in its August investor presentation, and CEO John Eric Francia said in April the company was on track to exceed 8 GW by the end of 2026, according to Philippine daily BusinessWorld.
Land acquisition problems have delayed other Philippine solar projects. In October 2024, at least 53 of 105 renewable energy projects under department review faced termination, and failure to secure possessory rights was among the reasons cited for delays. Earlier this month, the departments of energy and agriculture said they plan to separate land suitable for solar development from areas reserved for food production, under an agreement targeted for signing in October. The Philippines installed 899 MW of solar in 2025, bringing cumulative capacity to 3,892 MW.
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According to the latest IndexBox report on the global Solar Panels market, the market enters 2026 with broader demand fundamentals, more disciplined procurement behavior, and a more regionally diversified supply architecture.
The global solar panels market is entering a new phase of expansion, with the 2026-2035 forecast period expected to deliver a 9.2% CAGR, pushing the market index to 245 by 2035 (2025=100). This growth is underpinned by the accelerating energy transition, as governments and corporations ramp up renewable energy targets to meet decarbonization goals. Utility-scale power plants remain the largest end-use segment, but distributed generation in residential and commercial sectors is gaining momentum, supported by falling levelized costs and favorable policies.
Technological advancements, particularly in monocrystalline and bifacial modules, continue to improve efficiency and reduce costs, making solar power increasingly competitive with fossil fuels. However, the market faces headwinds from supply chain bottlenecks, trade restrictions, and raw material price volatility. Asia-Pacific dominates production and demand, but other regions are expanding rapidly. This report provides a data-driven analysis of the market dynamics, competitive landscape, and key trends shaping the industry through 2035.
The baseline scenario for the global solar panels market anticipates robust growth from 2026 to 2035, with a CAGR of 9.2%, culminating in a market index of 245 (2025=100). This outlook assumes continued policy support, technological improvements, and cost reductions. Utility-scale installations will remain the primary driver, accounting for over half of global demand, as countries seek to meet renewable energy targets. The residential and commercial segments will also expand, fueled by falling system costs and rising electricity prices.
Supply chain constraints, including polysilicon shortages and logistical challenges, are expected to ease gradually, but trade tensions and tariffs could disrupt regional markets. The market will see a shift toward higher-efficiency modules, such as HJT and perovskite tandem cells, although crystalline silicon will maintain dominance. Emerging applications like floating solar and BIPV will gain traction but remain niche. Overall, the market is poised for sustained expansion, with Asia-Pacific leading both production and consumption, followed by North America and Europe.
Utility-scale solar power plants represent the largest and fastest-growing segment of the solar panels market, accounting for over half of global demand. This segment is driven by large-scale tenders and auctions, where developers compete on price to secure long-term power purchase agreements (PPAs). The economics of utility-scale solar have improved dramatically, with LCOE now often below $0.03 per kWh in favorable regions. Through 2035, demand will be propelled by national renewable energy targets, corporate sustainability commitments, and the need to replace retiring fossil fuel plants. Key demand-side indicators include auction volumes, PPA prices, and grid interconnection queues.
However, challenges such as land availability, permitting delays, and grid integration may temper growth in some markets. Technological trends include the adoption of bifacial modules and trackers to boost energy yield, as well as the integration of storage to provide dispatchable power. Current trend: Increasing.
Major trends: Rising auction volumes and competitive bidding driving down PPA prices, Adoption of bifacial modules and single-axis trackers to increase energy yield, Integration of battery storage to enhance grid stability and dispatchability, Shift toward larger module formats and higher power classes to reduce balance-of-system costs, and Growing focus on repowering older solar farms with more efficient modules.
Representative participants: NextEra Energy, Iberdrola, Enel Green Power, TotalEnergies, ACWA Power, and Adani Green Energy.
The commercial and industrial (C&I) segment is a rapidly expanding market for solar panels, driven by businesses seeking to reduce energy costs, meet sustainability goals, and hedge against volatile electricity prices. C&I installations are typically rooftop or ground-mounted systems ranging from a few hundred kilowatts to several megawatts. Demand is supported by favorable economics, including declining module prices and innovative financing models such as power purchase agreements (PPAs) and leases. Through 2035, growth will be fueled by corporate net-zero commitments, rising retail electricity prices, and the availability of green financing.
Key indicators include commercial construction activity, corporate sustainability reports, and the penetration of third-party ownership models. Technological trends include the use of high-efficiency modules to maximize rooftop area, smart inverters for grid services, and integration with energy management systems. Current trend: Increasing.
Major trends: Corporate PPAs and green tariffs enabling off-site renewable procurement, Rooftop solar adoption driven by falling costs and sustainability mandates, Integration with energy storage and EV charging infrastructure, Digitalization and smart monitoring for optimized performance, and Growth in emerging markets as financing mechanisms mature.
Representative participants: SunPower, Tesla Energy, Schneider Electric, Siemens, ENGIE, and Brookfield Renewable.
Residential rooftop solar is a key segment of the solar panels market, driven by homeowners seeking to reduce electricity bills, increase energy independence, and contribute to environmental sustainability. Demand is highly sensitive to retail electricity prices, installation costs, and government incentives such as tax credits and net metering. Through 2035, growth will be supported by declining system costs, rising awareness of climate change, and the proliferation of financing options like solar loans and leases. Key demand-side indicators include housing starts, electricity price trends, and policy support.
Technological trends include the adoption of high-efficiency monocrystalline modules, building-integrated photovoltaics (BIPV) for aesthetic appeal, and smart home energy management systems. However, growth may be constrained in markets where net metering policies are weakened or where grid connection fees are imposed. Current trend: Increasing.
Major trends: Falling system costs and innovative financing expanding access to solar, Growing adoption of BIPV and solar tiles for new construction, Integration with home batteries and smart home ecosystems, Policy shifts from net metering to self-consumption models, and Rising demand for resilience against grid outages.
Representative participants: Sunrun, Vivint Solar, Tesla Energy, SunPower, Enphase Energy, and SolarEdge.
The off-grid and remote power segment serves areas without access to reliable electricity grids, including rural villages, remote industrial sites, and telecommunications towers. Demand is driven by the need for reliable, cost-effective power in locations where extending the grid is prohibitively expensive. Solar panels, often coupled with battery storage, provide a clean and sustainable alternative to diesel generators. Through 2035, growth will be supported by declining costs, improved battery technology, and international development programs aimed at achieving universal energy access. Key indicators include rural electrification rates, telecom infrastructure expansion, and humanitarian aid budgets.
Technological trends include the use of portable and plug-and-play solar kits, high-durability modules for harsh environments, and integrated energy storage. However, growth may be limited by financing constraints and lack of technical expertise in some regions. Current trend: Moderate.
Major trends: Declining costs of solar-plus-storage systems making off-grid solutions more affordable, Expansion of telecom networks driving demand for reliable remote power, Government and NGO programs promoting rural electrification, Adoption of portable solar products for outdoor and emergency use, and Integration with mini-grids for community-level power supply.
Representative participants: Off-Grid Electric, d.light, SunPower, Schneider Electric, Tesla Energy, and SMA Solar Technology.
The transportation and consumer electronics segment represents a small but emerging market for solar panels, with applications ranging from solar-powered vehicles and charging stations to portable chargers and wearable devices. Demand is driven by the push for sustainable mobility and the proliferation of IoT devices. Through 2035, growth will be supported by advancements in lightweight, flexible solar technologies and the increasing electrification of transport. Key indicators include EV sales, investment in solar infrastructure, and consumer adoption of portable solar products. Technological trends include the development of high-efficiency flexible thin-film modules, integration into vehicle surfaces, and solar-powered charging stations.
However, growth may be constrained by the limited surface area available on vehicles and the relatively low power output of portable panels. Current trend: Emerging.
Major trends: Integration of solar panels into electric vehicles to extend range, Expansion of solar-powered EV charging infrastructure, Growing demand for portable solar chargers for consumer electronics, Development of lightweight, flexible modules for transportation applications, and Use of solar panels in IoT devices and remote sensors.
Representative participants: Tesla, Toyota, Sono Motors, Lightyear, SunPower, and LG Electronics.
Interactive table based on the Store Companies dataset for this report.
Asia-Pacific leads both production and consumption, driven by China’s massive manufacturing base and ambitious renewable energy targets. India and Japan are also key markets. Growth will be supported by favorable policies and falling costs, though grid integration and land availability pose challenges. Direction: Dominant and growing.
North America is a major market, with the U.S. accounting for most demand. Growth is driven by federal tax credits, state-level renewable portfolio standards, and corporate procurement. Trade policies and supply chain constraints may impact growth, but the long-term outlook remains positive. Direction: Growing steadily.
Europe is a mature market with strong policy support for renewables. The EU’s Green Deal and national targets drive demand, but growth may be tempered by grid bottlenecks and permitting delays. Eastern Europe offers untapped potential. Direction: Growing moderately.
Latin America is an emerging market, with Brazil, Chile, and Mexico leading installations. Growth is driven by auctions and corporate PPAs. Economic volatility and policy uncertainty are key risks, but the region’s high solar irradiation offers significant potential. Direction: Emerging growth.
The Middle East and Africa are poised for rapid growth from a small base, driven by abundant solar resources and falling costs. Countries like Saudi Arabia, UAE, and South Africa are investing in large-scale projects. Off-grid solar also plays a crucial role in expanding energy access. Direction: Emerging growth.
In the baseline scenario, IndexBox estimates a 9.2% compound annual growth rate for the global solar panels market over 2026-2035, bringing the market index to roughly 245 by 2035 (2025=100).
Note: indexed curves are used to compare medium-term scenario trajectories when full absolute volumes are not publicly disclosed.
For full methodological details and benchmark tables, see the latest IndexBox Solar Panels market report.
This report provides an in-depth analysis of the Solar Panels market in the World, including market size, structure, key trends, and forecast. The study highlights demand drivers, supply constraints, and competitive dynamics across the value chain.
The analysis is designed for manufacturers, distributors, investors, and advisors who require a consistent, data-driven view of market dynamics and a transparent analytical definition of the product scope.
This report covers photovoltaic (PV) solar panels, which are devices that convert sunlight directly into electricity. It encompasses the global market for finished modules, including all major product technologies and form factors designed for a wide range of end-use applications.
The market data is classified and analyzed according to international trade codes, primarily under the Harmonized System (HS) headings for photovoltaic cells and electric generating sets. This ensures consistent tracking of trade flows for assembled solar modules and relevant apparatus across global markets.
World
The analysis is built on a multi-source framework that combines official statistics, trade records, company disclosures, and expert validation. Data are standardized, reconciled, and cross-checked to ensure consistency across time series.
All data are normalized to a common product definition and mapped to a consistent set of codes. This ensures that comparisons across time are aligned and actionable.
Report Scope and Analytical Framing
Concise View of Market Direction
Market Size, Growth and Scenario Framing
Commercial and Technical Scope
How the Market Splits Into Decision-Relevant Buckets
Where Demand Comes From and How It Behaves
Supply Footprint, Trade and Value Capture
Trade Flows and External Dependence
Price Formation and Revenue Logic
Who Wins and Why
Where Growth and Supply Concentrate
Commercial Entry and Scaling Priorities
Where the Best Expansion Logic Sits
Leading Players and Strategic Archetypes
Detailed View of the Most Important National Markets
How the Report Was Built
World's largest solar wafer manufacturer
Consistently top module shipper globally
Major producer of cells and modules
Pioneer in module technology and Vertex series
Vertically integrated, strong in project pipeline
Largest US-based manufacturer, unique technology
Major investment in US manufacturing
Significant producer with heterojunction focus
World's largest solar cell producer
Maxeon manufactures SunPower's legacy technology
Pioneer in heterojunction technology
Part of GCL Group, large-scale manufacturer
Vertically integrated under Chint Group
Significant global shipments
Major Indian manufacturer with global presence
Part of Adani Group, large integrated capacity
Exited solar business in 2022 but legacy remains
Historic leader, now smaller scale
Largest US residential solar company
Former industry leader, still significant
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Nio began operating a battery swap station in China’s Gobi Desert that runs entirely on solar power and on-site energy storage, with no connection to the power grid.
The Chinese EV maker announced the opening of the Silk Road Xingxingxia station on its official Weibo account on Wednesday.
Nio claimed that the facility is the world’s first zero-carbon, off-grid battery swap station powered by solar generation and storage.
Located at the Xingxingxia service area on the G30 Lianyungang-Horgos Expressway, the station sits on the main road into Xinjiang.
Nio said the facility runs 24 hours a day with solar as its only energy source.
Co-founder and president Lihong Qin said at the opening ceremony that the project is Nio’s first deployment to validate off-grid battery swapping and will provide experience for expansion into similar regions.
Chinese solar manufacturer Longi Green Energy Technology supplied the station’s photovoltaic and storage hardware.
The site uses Longi’s Block mobile energy station and Longi’s H2D energy storage system.
Nio and Longi signed a strategic cooperation agreement on January 3, 2024, to promote photovoltaic power at charging and battery swap stations, according to a Nio statement reported by both Gasgoo and CnEVPost.
The agreement also covered vehicle-to-grid technology and industry standards for carbon-neutral mobility.
Their first jointly built HPBC (Hybrid Passivated Back Contact) photovoltaic swap station opened at the Xi’an Olympic Sports Center at the time.
Nio also said its fourth-generation stations would carry 60 square meters of solar panels each, saving nearly 18,000 kWh of electricity per station per year.
The Shanghai-headquartered EV maker describes the setup as a closed “generation-storage-use” loop.
Solar panels power the station directly during daylight hours and send surplus electricity into storage. Stored energy discharges overnight to keep swaps running.
During prolonged cloudy weather, the system switches automatically into an emergency mode and reserves power for critical loads.
Moving between the three operating modes requires no manual intervention, according to the company.
Liquid-cooled temperature control and a high-protection design keep the system stable in desert conditions, according to the company.
Xingxingxia lies in the eastern Gobi Desert, in a region with weak grid coverage. Winds reach force 8 or higher on more than 100 days a year.
Summer surface temperatures can exceed 70°C, while winter temperatures can fall to -30°C.
Extending the conventional grid to the site would require laying power lines across long stretches of desert, with lengthy construction periods and high costs, Nio said.
Remote western regions have lagged Nio’s swap buildout elsewhere in China.
Founder and CEO William Li said in July that full nationwide county-level swap coverage was about two years away, with exceptions for remote areas of Xinjiang and Tibet.
Xingxingxia serves as a key node on Nio’s Silk Road battery swap route, which is scheduled to be fully connected on September 26.
The corridor spans 3,605 kilometers and includes 33 swap stations.
Once the route opens, users will be able to depart from any Nio swap station in China and reach every provincial-level administrative region on the mainland using battery swaps alone, the company said.
Nio opened the first phase of the corridor, the Hexi Corridor route, on May 10.
The segment covers 1,739 kilometers from Xi’an to Dunhuang, with 20 swap stations spaced about 87 kilometers apart, according to Gasgoo.
A station at the Jinghe service area in Xinjiang’s Bortala Mongol Autonomous Prefecture came online over the weekend.
In May, Nio had guided to a 3,448-kilometer route with more than 30 swap stations. The final corridor is 157 kilometers longer.
The new route supersedes an earlier version.
In July 2023, Nio announced a Silk Road route from Xi’an to Horgos covering 3,133 kilometers with 33 combined charging and swap stations. Every facility on the new route is a swap station.
As of Wednesday, Nio operated 4,109 battery swap stations in China, including 1,060 on highways.
The company crossed the 4,000-station mark in early August, when it also opened its first fifth-generation units across seven cities.
The company also ran 5,301 charging stations with over 30,500 charging piles and provided access to more than 1.7 million third-party charging piles.
Nio ended 2025 with 3,676 swap stations in China.
The current total implies 433 stations added so far in 2026, or 43.3% of the company’s target of more than 1,000 new stations this year.
Nio began large-scale deployment of its fifth-generation stations in late July after repeated delays, and had planned about 450 of them for the fourth quarter alone.
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Global alternative asset manager Blackstone Infrastructure has completed the acquisition of a 24.7% stake in Danish independent power producer (IPP) Eurowind Energy.
Blackstone will commit to invest up to DKK15 billion (US$2.3 billion) to accelerate the growth of the Danish renewable energy developer across Europe.
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The investment will support Eurowind Energy’s goal to become a pan-European IPP with a target to develop 1.5GW of new solar PV, wind and energy storage capacity per year through 2030.
Jens Rasmussen, CEO, co-founder and co-owner of Eurowind Energy, added that the company expects to construct nearly four to five times as much new capacity every year compared with 2025.
At the end of last year, the company had 1.5GW of operational renewables assets, with a further 1.3GW in construction in its own portfolio and a development pipeline of 56GW, of which 14.5GW is solar PV and 15.8GW is energy storage.
“Closing this transaction marks an important new chapter for Eurowind Energy. We have built a strong European platform over the past 20 years, and with Blackstone as a long-term partner, we now have the financial strength to significantly increase the number of renewable energy projects we develop, build and own, thereby contributing to the expansion of renewable energy capacity in Europe,” said Gert Vinther Jørgensen, chair of the board of Eurowind Energy.
Jørgensen is also the group CEO of Danish energy and telecommunications cooperative Norlys, which owns a 37.65% ownership interest in Eurowind Energy.
Blackstone’s stake acquisition of Eurowind Energy comes only days after the Danish IPP completed the acquisition of German renewables company EnBW’s Swedish renewables platform. This acquisition marked a significant expansion into the renewables market in Sweden.
Moreover, Blackstone’s investment in Eurowind Energy comes at a time when important European renewables companies have had financial troubles, such as German developer Enerparc’s recent filing for insolvency. Analysts who spoke with PV Tech Premium said that Enerparc’s insolvency could signal the start of broader consolidation in the European solar sector (subscription required).
The United States crossed 100 GWp-dc of cumulative solar PV module production during the second quarter of 2026, the subject of my recent article on pv magazine.
But how much did the United States spend on solar PV manufacturing capital expenditure (capex) to achieve this milestone?
Background research by the author – undertaken on the build up to the Solar Manufacturing USA 2026 conference in Austin Texas on 22-23 September 2026 – places this at about $21 billion of U.S. solar manufacturing capex. This covers a period of more than 50 years, going back to the commercial origins of U.S. solar PV manufacturing in the early 1970’s through to the end of Q2 2026, when the 100 GW cumulative production volume was achieved.
This $21 billion of cumulative capital deployed into U.S. solar PV manufacturing assets includes a wide range of spending outcomes: factories that succeeded, many that failed, and plenty of production equipment that never generated anything close to its intended purpose.
Manufacturing capex is defined as spending on factory buildings for commercial manufacturing operations, the related infrastructure and production equipment, and maintenance/upgrade spending. The analysis excludes R&D spending and its related infrastructure, and pilot lines.
I estimate First Solar’s domestic manufacturing capex allocations to represent about one-quarter of all U.S. PV manufacturing capex. This starts with the original Perrysburg, Ohio, factory to the recent Alabama, Louisiana and South Carolina additions.
Therefore, by the end of Q2 2026, First Solar accounted for about one-quarter of cumulative manufacturing capex supported by about two-fifths of the cumulative module production in the United States, dating back to the starting point for the country’s solar manufacturing aspirations in the early 1970’s.
For those that have tracked First Solar production and capex over the past few decades and its focus on the United States, these statistics will not come as any surprise. For years leading up to the introduction of the Inflation Reduction Act at the end of 2022, the domestic U.S. solar manufacturing sector was essentially First Solar and ‘everyone-else’.
Figure 1: At the end of Q2 2026, when cumulative U.S. solar module production reached the 100 GW point, First Solar is estimated to account for almost one-quarter of solar PV manufacturing capex in the United States going back to the first investments in U.S. solar manufacturing in the early 1970’s.
First Solar is the only meaningful company making thin-film solar modules in the United States. The company is also the only entity of significance making thin-film modules globally.
However, for a five-year period about 15 years ago, capex allocations for new solar PV manufacturing sites in the United States painted a different picture.
Excluding the domestic capex of First Solar, I estimate that about $3.4 billion of U.S. manufacturing capex went into other thin-film companies, concentrated heavily in the 2007-2012 boom.
During this period, Unisolar, Solyndra, Abound Solar, Global Solar, MiaSolé, Stion, Nanosolar, HelioVolt, SoloPower and others created an extraordinary factory-building cycle across the full range of thin-film variants including amorphous silicon, CIS/CIGS and CdTe. However, these companies’ cumulative (and legacy) contribution to the 100 GW module production landmark is only in the 1% range.
Much of this $3.4 billion in capital was written off, stranded or absorbed by factories that operated briefly.
The crystalline-silicon history of capex spend in the United States is equally informative. From the industry’s beginnings in the early 1970’s through to the end of 2017, I estimate cumulative U.S. c-Si manufacturing capex at about $3.9 billion.
This spending spans several generations; Arco Solar and Solarex, BP and Shell, SolarWorld, Evergreen Solar, Suniva, and Japanese entrants. But the spending here never produced a durable, scaled domestic c-Si sector.
Section 201 created a partial c-Si capex uptick. This safeguard period helped bring initial module manufacturing back to the United States in modest volumes through companies including Qcells, JinkoSolar, LG Electronics, Silfab and Heliene. However, most of the capex activity remained focused on downstream module assembly.
The real uptick in c-Si capex comes after the Inflation Reduction Act and Section 45X. From 2023 through Q2 2026, c-Si manufacturing capex accounts for almost 40% of all the PV manufacturing capital deployed in the United States since the industry’s beginnings, concentrated into just three and a half years.
In fact, the post-IRA c-Si capex total is already roughly twice the amount invested across the entire 1970-2017 c-Si period. It also exceeds all pre-IRA c-Si capex combined, with the current investment cycle spanning Qcells, T1 Energy, Canadian Solar and a much broader group of new U.S. entrants.
The first 100 GW therefore cost the United States about $21 billion in cumulative manufacturing capex, but the money was distributed unevenly. Almost one-quarter went into First Solar; another one-sixth went into a thin-film boom whose production legacy was minimal; and nearly two-fifths has arrived only since the start of the post-IRA c-Si cycle.
Going forward, can the elevated levels of capital now being deployed into U.S. c-Si manufacturing translate into sustained production, high utilization and long-lived factories?
The historical record shows that spending money is the easy part, with First Solar’s quarter-century of continuous U.S. manufacturing the exception. The durability of the post-45X build-out, coupled with the increased capex arising from the introduction of Section 232, will determine whether the next 100 GW looks fundamentally different from the first.
To understand more about the companies currently committing capex to existing or new solar PV manufacturing sites in the United States, the new Solar Manufacturing USA Quarterly report from Terawatt PV Research provides an ideal reference point. The report also features analyses on current solar PV manufacturing sites, with production and capex for each company forecast out to the end of 2030.
To learn more about the report and subscription options, please send an email to the pv magazine USA team at [email protected].
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With the recent expansion of a solar array near the University of Toledo Medical Center, UToledo is more than doubling its capacity for solar energy production on Health Science Campus while creating opportunities for student learning and research.
The University will celebrate the completion of the project with a ribbon-cutting ceremony beginning at 10:30 a.m. Thursday, Sept. 24. The array is located along Main Technology Drive, and the ceremony is set to take place in the adjacent Parking Area 44E.
UToledo will celebrate the completion of a solar array expansion near UTMC with a ribbon-cutting ceremony at 10:30 a.m. Thursday. The array is located along Main Technology Drive, and the ceremony is set to take place in the adjacent Parking Area 44E.
“This project is an exciting, real-world demonstration of the importance of the groundbreaking advances being made at First Solar and the strong connection to our work at the Wright Center for Photovoltaics Innovation and Commercialization,” said Dr. Michael Heben, a Distinguished University Professor and the Helen and Harold McMaster Chair and Director of UToledo’s Wright Center for Photovoltaics Innovation and Commercialization.
“In addition to the economic and environmental benefits, this array serves as an educational asset for our science and engineering students, offering hands-on experience with commercial-scale renewable energy systems. I applaud the hard work done by the Student Green Fund, Michael Green, director of energy sustainability and energy efficiency at UToledo, Dr. Randy Ellingson, a Distinguished University Professor and Wright Center for Photovoltaics Endowed Professor, and our friends at First Solar for making this all happen.”
The original installation has generated more than 2.6 million kilowatt-hours of clean energy since it came online in late 2020. When combined with a reduction in peak electrical demand, this translates to a total economic impact of nearly $275,000.
The expansion increases the nameplate capacity of the array from 330 to 750 kilowatts, more than doubling its expected annual electrical production. This annual electrical production is now estimated at more than $70,000, in addition to peak-demand savings.
As a student-driven initiative that benefits from cutting-edge technology donated by First Solar, the project reflects the power of student leadership, community partnership and research excellence at UToledo.
The array is the flagship project of the Student Green Fund, a committee of undergraduate and graduate students that administers the voluntary $5 fee that students are assessed each semester in partnership with UToledo’s Office of Sustainability. The fund has supported numerous student-led initiatives since its establishment in 2017, including the installation of high-efficiency hand dryers in campus bathrooms and refillable water bottle stations in high-traffic buildings on Main Campus and Health Science Campus.
The Student Green Fund contributed $350,000 to cover the first-phase installation of the solar array and $530,000 to cover the second-phase expansion.
The array is also supported by First Solar, the solar technology giant with a significant footprint in Northwest Ohio and long-standing ties to UToledo. First Solar donated Series 5 modules for the first phase and now Series 6 Plus modules for the second-phase expansion.
First Solar specializes in a type of photovoltaic technology that utilizes cadmium telluride.
UToledo is a global leader in the research and development of cadmium telluride and other thin-film technologies. University physicists — including two who are credited among the most highly cited researchers in the world — routinely publish ground-breaking research that supports a broader distinction in materials science that positions UToledo among U.S. News & World Report‘s Best Global Universities.
“This solar array project has grown into a sustainable system that improves our campus utilities while supporting community electrical grid reliability,” said Michael Green, director of energy sustainability and energy efficiency at UToledo. “It would not have happened without the Student Green Fund and First Solar. As we evaluate third-phase expansion, I look forward to working together to further sustainable systems development at UToledo.”
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Solex Energy Limited, a solar photovoltaic module manufacturer and EPC services provider, outlined its expansion plans and growth strategy at its 12th Annual General Meeting, with the company targeting revenue potential of more than ₹4,500 crore by FY28. The company reported revenue of ₹16,211 million for FY26, up 143.9 per cent year on year. EBITDA stood at ₹1,867 million and Profit After Tax was ₹983 million. Solex also reported order visibility of more than ₹34,000 million.
Addressing shareholders, Dr Chetan Shah, Chairman and Managing Director, Solex Energy Limited, said, “Nearly three decades ago, Solex began with a belief in the potential of solar energy. Today, that belief has evolved into a much larger ambition. We are building Solex not merely to participate in the energy transition, but to build the capabilities that will shape the next generation of energy.”
The company is expanding beyond its solar module business into solar cell manufacturing and Battery Energy Storage Systems (BESS). Solex plans to establish 2.2 GW of solar cell capacity by FY28 and increase this to 5.2 GW by early FY29. In energy storage, the company is developing capabilities for 10 GWh of battery pack and container assembly. The first 5 GWh phase is targeted for FY29. Solex said storage will become increasingly relevant as electricity demand rises across electric mobility, industrial electrification, data centres, artificial intelligence and other energy-intensive applications.
The company has outlined an investment programme of around ₹4,000 crore between FY27 and FY30. The programme includes the planned solar cell capacity expansion and BESS manufacturing capabilities. Solex said the move into solar cells will provide greater control over quality, costs and supply chains while expanding its participation in India’s domestic solar manufacturing ecosystem. The combination of solar generation and storage is also expected to support the company’s plans to serve a broader range of energy requirements.
The company is also developing an international presence through plans for Solex Europe and Solex USA. These initiatives will focus on developing long-term customer relationships and expanding the company’s presence in international solar markets. Solex operates a 4 GW photovoltaic module manufacturing facility at Tadkeshwar, Gujarat. The Industry 4.0-enabled facility uses automated production systems, real-time quality controls and data-driven manufacturing processes. The company also provides EPC solutions for utility-scale, commercial, industrial and institutional projects.
The AGM reviewed the company’s FY26 performance and outlined its next phase of expansion across solar cells, modules, energy storage and international markets. Solex said the planned investments are aimed at building an integrated renewable energy business while maintaining focus on capital deployment, technology and execution.
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Now that Winter is soon upon us, leaves are turning, and high electric bills will soon be here, I think back to August when PVs blossomed in the town park at the Energy Fair. But, wait a minute. PVs? Oh, yes. Photovoltaics, from the Greek photos (light) and the Italian Alessandro Volta, (1745-1827), who first named the electromotive force. These magic things that give juice purely from the light are generally called solar electric panels by their marketeer, and solar cells by the R&D scientific crowd. The best simple explanation is in the intro to the 1992 Designer’s Guide from Alternative Energy Engineering: “The solar cell is a two layered silicon semi-conductor device.”
New research from solar and energy storage data firm Anza shows that solar module prices are spiking, following the second Trump administration’s Aug. 6 decision on Section 232.
The decision, which imposes new tariffs on polysilicon materials, could have wide-reach effects across the whole of the American industrial landscape. Along with consumer electronics, solar and energy at large are two sectors that the proclamation will impact the most.
Anza says that in the month since the decision, “the solar module market has moved quickly from uncertainty to repricing, with developers now moving quickly to secure lower-cost supply before the minimum import price takes effect.” Suppliers continue to adjust their pricing and in turn, developers have continued to weigh whether to secure modules already on American shores, accelerate imports, or shift their supply chain strategy entirely.
“The industry has been preparing for potential Section 232 impacts for months, and we are now entering the most critical procurement window,” says Anza president Aaron Hall. “December 4 may be the effective date, but developers can’t treat it as the deadline to make a procurement decision.”
In response to the new data, Anza has outlined a few immediate steps to take before the Dec. 4 effective date. The company recommends that developers immediately reassess procurement plans across a set of four areas.
First, the company urges developers and suppliers to prioritize inventory already in the U.S. Officials state that “developers should assess available manufacturer and peer-held inventory now, before supply tightens.”
Additionally, Anza officials have asked solar firms to evaluate what will clear American customs before Dec. 4. This will help the industry local down domestic cell and wafer capacity, which remains limited.
“Modules need time to ship and clear U.S. Customs before (Dec. 4), and lower-cost supply available ahead of the deadline is already tightening,” Hall says. “Developers need to understand what is available now, at what price and on what terms, and move quickly on the strategy that makes the most sense for their project.”
Finally, the company says that solar companies should address tariff exposure in contracts going forward. This will give insight into how foreign companies allocate retroactive tariff and stockpiling exposure.
Anza says it has helped solar industry customers navigate module procurement for more than 5 GW of solar over the past calendar year.
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Local solar installer Pisgah Energy recently completed a series of solar projects for Mountain Housing Opportunities (MHO), a non-profit community developer in Asheville, North Carolina, that helps create more affordable and sustainable futures for families in the area. MHO’s newest housing communities, Star Point Apartments and Lakeshore Villas, sport solar arrays that will contribute to cleaner air…
The post Pisgah installs additional solar projects for Asheville community housing developer appeared first on Solar Power World.
Workers monitor operations in the control room of a photovoltaic power station operated by Huadian (Beijing) New Energy Development Co. Ltd. in Beijing, Wednesday, Sept. 23, 2026.
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Solmatix has completed a significant solar PV and battery storage installation at Donegall Pass Community Centre in Belfast, supporting the transition towards more sustainable and energy-efficient public buildings.
The installation is comprised of a 30.015kWp rooftop solar PV system comprising 69 high-performance 435W panels, a hybrid inverter and integrated battery storage.
Designed, installed and commissioned by Solmatix, the system is expected to generate approximately 21,371kWh of renewable electricity annually, which is predicted to save the council £7,000 per year. The battery storage will allow more of the electricity generated on site to be retained and used by the centre when required.
The project also includes enhanced monitoring technology, allowing the performance of individual panels to be tracked and helping the centre identify any maintenance or performance issues quickly.
The installation supports the wider direction set out in Belfast’s Net-Zero Carbon Roadmap and Local Area Energy Plan, which identify the decarbonisation of buildings and the development of a more resilient, affordable and low-carbon energy system as important priorities for the city.
Since the installation was completed earlier this year, Belfast City Council has reported that the community centre was effectively ‘off-grid’ for more than 80% of the time in the first 3 months of the project. The array is expected to help reduce carbon emissions by 13 tonnes of CO2e/KWh annually.
This project will be used as a pilot scheme to assess the viability of a move to rooftop solar for more buildings across the council estate.
Donegall Pass Community Centre provides facilities, activities and services for people and community organisations in the surrounding area. Completing the installation within an operational community facility required careful coordination between Solmatix, the centre management team and the other parties involved in the project.
Solmatix managed the technical design, equipment supply, rooftop installation, electrical works, battery integration, monitoring technology, testing and commissioning.
Neville Bell, Managing Director of Solmatix, said: “This project demonstrates how renewable energy investment can deliver practical, long-term benefits for important community facilities.
“The solar PV system will allow Donegall Pass Community Centre to generate a meaningful proportion of its electricity on site, while the battery storage helps the centre make better use of that renewable energy throughout its operating day.
“Our team worked closely with everyone involved to design and deliver a solution suited to the building and the way the centre operates. The installation combines solar generation, battery storage and detailed performance monitoring in one integrated system.
“Projects such as this show the important role public and community buildings can play in the transition to cleaner energy. We are proud to have delivered this investment at a centre which provides such valuable services to its local community.”
The rooftop array has been designed around the available south-facing roof area, with the 69 panels arranged to maximise renewable energy generation while meeting the technical and safety requirements of the building.
A generation display has also been incorporated into the project, providing a visible way for centre users and visitors to see how much renewable electricity the system is producing. Additional controls will help the centre make productive use of available solar generation, while the monitoring system provides greater oversight of the performance of the installation.
The project adds to Solmatix’s growing portfolio of public sector, education, healthcare, commercial and community-based renewable energy installations across the UK and Ireland.
Established in 2008, Solmatix has completed more than 750 installations in the last three years alone, representing approximately 39MW of renewable energy capacity.
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On September 21, the Jiaxing Municipal Ecology and Environment Bureau of Zhejiang Province issued a public notice regarding its intention to approve the environmental impact assessment documents for the high-efficiency new-structure cell and module technological transformation project of Zhejiang Jinko Solar Co., Ltd.
According to the notice, Zhejiang Jinko Solar Co., Ltd. (hereinafter referred to as "Zhejiang Jinko") plans to invest 179.2 million yuan to implement the high-efficiency new-structure cell and module technological transformation project within its existing factory buildings. The project will phase out outdated equipment such as texturing machines and tabbing and stringing machines, introduce advanced equipment for wet processing and patterning, and deploy digital and intelligent systems including MES, SAP, and AI, thereby achieving a comprehensive technological upgrade.
The factory undergoing this technological transformation by Zhejiang Jinko is located in Haining City, with existing capacity of 6 GW of crystalline silicon cells and 6 GW of cell modules.
After the implementation of the above technological transformation project, the existing capacity of 6 GW/a of cells and 6 GW/a of modules will be fully phased out, while the R&D activities for solar cells will be retained. The entire plant will then achieve an annual production capacity of 2.7 GW/a of high-efficiency new-structure cells and 4 GW/a of modules.
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Luis Reyes
Sep 23, at 9:30am ET
Corn is about as sun-hungry as crops get. Ask any farmer, or anyone who’s tried squeezing a few stalks into a shady backyard, and you’ll hear the same rule: full sun or don’t bother. So when a French solar company reported last week that the corn under one of its panel canopies outyielded the corn in the open field beside it, I figured there’d be a catch.
There’s a catch, sort of, and it’s the weather. France spent this spring and summer in exceptional drought and heat, and in a year like that a cornfield has more sunlight than it can use and less water than it needs.
The field sits in Amance, in eastern France, under an agrivoltaic demonstrator built by TSE, a French solar developer. The canopy holds 5,500 rotating solar panels 16.4 feet (5 meters) over working farmland, high enough that “all our equipment passes under the structure,” as Sylvain Raison, the farmer who runs the land, puts it on TSE’s project page. Per that same page, the trial splits the land into roughly 7.4 acres (3 hectares) under panels and a 4.9-acre control strip in the open.
Silage corn went into the ground on April 25. If you’re not familiar, silage corn isn’t the sweet corn you’d grill in August. The whole plant gets chopped up, stalk and all, and fed to cattle. So the harvest gets measured in total plant matter rather than pretty ears. We’ve covered sweet corn growing under solar panels before, and that’s a different game.
Then the season did its worst. April passed without rain right as the corn was emerging, and the heat landed during stem elongation and flowering, the stretch where corn handles stress worst. Out in the open control plot, temperatures topped 95°F (35°C).
By harvest, pv magazine reports, the corn under the panels had put on 19.6 percent more dry matter than the corn in the open, and the plants averaged 79 inches tall against 63 inches in the control rows. Ear sterility showed up on both sides, though it hit the open plot hardest. TSE’s own read was that “the canopy provided the expected protective effect,” which is corporate-speak for the shade doing its job.
That height gap is the number that gets me, frankly. A 16-inch difference in average plant height isn’t something you’d need a lab to detect. You could see it from the road.
The short answer is water. A canopy that blocks part of the midday sun also cuts how much water the field sweats out under it, and this year that’s the trade that paid off.
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The measured version of that comes from TSE’s other instrumented site, in Chadeleuf in central France, where 392 solar panels stand over winter barley and the ground carries 14 weather stations, 18 radiation sensors and 14 soil probes. Over the growing season, evapotranspiration under that canopy ran 20 percent below the open field. During heat spikes, the air at crop height stayed 7.4°F (4.1°C) cooler at the hottest point of the day, and the field held on to about 0.08 inches (2.15 mm) more water per day. On the coldest nights, the canopy kept the air up to 5.4°F (3°C) warmer.
Evapotranspiration, if the word’s new to you, is basically the water a field loses to the sky. Some evaporates off the soil, and the rest gets breathed out by the plants themselves. Cut it by a fifth and the soil stays moist longer between rains, which is a rounding error in a wet year and pretty much the whole ballgame in a drought.
There’s a second reason the Chadeleuf barley matters. French law caps the yield loss an agrivoltaic installation is allowed to cause at 10 percent, and the canopy gets measured against that cap every season.
TSE runs the rotating panels under different steering programs, which are basically different answers to how much light goes to the crop and how much goes to the panels. Under one program the barley came in at 96 percent of the open plot’s yield, and under the other it came in at 90 percent, so they’re both inside the legal line. The grain’s specific weight, a standard quality measure, ran 3 percent higher under the canopy. The barley came off the field in late June.
Now, these are TSE’s own demonstrators, and you’d expect a solar company to lead with its most flattering numbers. Credit where it’s due, though. The harvest was run by Antédis, an agronomic research firm, and the monitoring was validated by the Puy-de-Dôme Chamber of Agriculture and a local technical institute, per TSE and pv magazine. That’s still a long way from peer-reviewed science, but it’s a step up from a company grading its own homework.
TSE hasn’t published absolute tonnage for either field, so I can’t tell you what the plots produced per acre, only how they compared. The company also says the crop-quality analysis on the corn arrived recently and hasn’t been fully worked through, so whether all that extra plant matter makes equally good cattle feed is still an open question.
Corn’s pretty much the crop in the United States, so the obvious question is whether anyone will build canopies like this over the Midwest.
I wouldn’t hold my breath.
A 16-foot structure a combine can drive under is serious infrastructure, and stateside agrivoltaics has so far mostly meant sheep grazing under utility arrays and smaller specialty plots, like the Colorado berry farm that went under 3,276 panels after drought cut off its irrigation water. Still, the water math travels. Drought isn’t exactly a foreign concept in the corn belt, and as far as I can tell, this French campaign is the strongest set of row-crop results that’s been put on paper for agrivoltaics anywhere, with yield, plant height, water use and temperature all measured, and all favoring the canopy in the same brutal season.
TSE published the campaign results on September 18, and says it’s now working through the crop-quality analysis from the Amance harvest. Until the quality numbers land, the corn’s 19.6 percent stands, measured in a season of exceptional drought and heat.
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Chema Bonilla Díaz · Sep 22, 2026
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Abu Dhabi’s utility, Emirates Water and Electricity (EWEC), is targeting more than 35GW of solar capacity by 2035.
The utility has set an interim target of 14GW of PV by 2030, up from an earlier target of 10GW, as it scales its installed capacity to beyond 35GW by the middle of the next decade.
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The planned PV deployment will be backed by 15GW of battery storage capacity, enabling ‘round-the-clock’ provision of solar-generated power.
The UAE has set increasingly ambitious renewable energy targets as it capitalises on its abundant solar resources, which make it one of the lowest-cost regions for PV-generated electricity worldwide.
Last month, state-run media reported comments from the Emirati energy minister that the UAE overall was aiming for renewables and nuclear energy generation to account for 35% of its energy mix by 2030-31.
In this latest statement of intent, Mohamed Almarzooqi, chief assets officer of EWEC, said: “We are actively procuring the utility-scale solar photovoltaic, battery storage and reverse osmosis desalination capacity required to deliver this outcome, structurally reducing the reliance of the system on gas-fired generation. Through this transformation, EWEC is enabling the UAE and Abu Dhabi to build a highly diversified, resilient, and low-carbon system that seamlessly meets rising demand while strengthening water and energy security.”
No further details were provided on how the solar targets will be met, but Abu Dhabi is already working on several solar and storage mega projects. These include a 5.2GW/19GWh round-the-clock solar-plus-storage facility that reached financial close in July and the 1.5GW Khazna solar plant, which also completed financing earlier this year. It is already home to the 1.2GW Noor solar power plant (pictured), one of the world’s largest standalone PV power plants.
EWEC said it was forecasting that carbon emissions from its power and water production would fall by over 45% by 2035, even as annual electricity demand is forecast to rise by around 70% 2026 and 2033.
The largest solar project in Milwaukee history is now powering the grid with renewable energy. Mayor Cavalier Johnson, Alderman Scott Spiker and other leaders gathered at the solar site on a sunny September day to mark the occasion.
The nearly 7-megawatt site near Milwaukee Mitchell International Airport can produce enough energy to power about 2,000 homes.
“This community solar project will help the city meet its environmental goals and provide our customers affordable, reliable and clean energy,” said Danielle Bly with We Energies.
The City of Milwaukee is supporting the project through the Renewable Pathway Program. The energy that feeds the grid can offset 80 city buildings, including fire stations and libraries.
“Supporting clean renewable energy is really important to me. It’s really important to the community overall in Milwaukee as well, because we all need reliable energy sources to power our buildings, to have our lights on, support our transit systems, and so much more now,” Mayor Johnson said at the event.
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Published by Abby Butler, Editorial Assistant
Energy Global,
Renalfa IPP has completed the repowering and hybridisation of another generating asset from its portfolio – the Devnya photovoltaic (PV) plant in Northeastern Bulgaria.
The Devnya PV plant had nominal capacity of 5 MWp and has been operating since 2011. After the repowering, the solar park now has an installed capacity of 65 MWp and has been hybridised with a co-located battery energy storage system (BESS) with capacity of 60 MW/165 MWh. Solarpro Bulgaria acted as project manager and EPC contractor.
This is another of Renalfa IPP’s assets that has been repowered and hybridised following to the company’s strategy for maximising the available grid connection by co-locating BESS to PV, optimising the value of the production profile and the sale of green baseload products. In November 2025 Renalfa IPP completed the repowering of its PV park Kaolinovo in Northeast Bulgaria. Project Kaolinovo was repowered from 10 MWp to an installed capacity of 60 MWp and hybridised with a co-located BESS with a capacity of 33 MW/110 MWh.
Renalfa IPP is an Austrian joint venture between Renalfa Solarpro Group, a clean energy and e-mobility company based in Vienna, and French renewable energy infrastructure fund manager, RGREEN INVEST.
Renalfa IPP is one of the leading investors and developers of renewable energy projects in Central and Eastern Europe with more than 806 MW of operation and generating assets and over 1 GWh of energy storage in operation. Renalfa IPP has another over 1.1 GW of generating projects and more than 3.5 GWh BESS in final stages of construction and development. The company is active in Hungary, Romania, Bulgaria, and North Macedonia.
The Autumn issue of 2026 is available now! The new issue begins with a regional report on Asia Pacific, looking at the region’s transition from building capacity to building systems. The issue also explores topics such as offshore wind foundations, solar maintenance, training the new workforce, inspection & maintenance, and more! With insights from experts such as Everllence, BW Ideol, EM&I, Watson Farley & Williams, and many more, make sure to check out this issue now.
Read the article online at: https://www.energyglobal.com/solar/23092026/renalfa-ipp-repowers-devnya-photovoltaic-park-to-65-mwp/
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Permitting remains one of the main obstacles to the development of floating photovoltaic projects in Romania, preventing the technology from fully translating its efficiency and profitability advantages into lower energy prices, Alessandro Amato, CEO of Waldevar Floating PV, said at the Green Energy Conference, organized by The Diplomat-Bucharest.
“Our clients are facing problems when it comes to permitting. They expect to see a benefit from this segment as well. In floating PV projects, however, we can see that, even when construction costs remain stable, the burden associated with permitting leads to higher energy prices,” Amato said.
According to Amato, floating photovoltaic systems can provide strong returns while also offering technical advantages compared with conventional ground-mounted solar installations.
“Our systems are capable of delivering high returns. In particular, those installed on water have higher efficiency because they are cooled by the water, while also requiring less space per hectare,” he said.
“However, this does not translate into a lower price yet, because there are still major barriers when it comes to permitting,” Amato added.
He stressed that the regulatory framework will be increasingly important as Romania seeks to expand renewable energy capacity, noting recent progress in the regulatory treatment of floating solar projects.
“The legislative framework is becoming extremely important. Romania has made some progress. Speaking specifically about floating solar, in 2025 an order was introduced that regulated, for example, the use of water surfaces managed by the state for photovoltaic energy,” Amato said.
At the same time, the development of hundreds or thousands of smaller renewable power plants will require an electricity grid capable of accommodating increasingly decentralized generation, he said.
“We have to consider that all these hundreds or thousands of smaller power plants also need a grid that is properly developed or designed for such a situation,” Amato said.
He acknowledged the strategic importance of state control over water resources, while arguing that the regulatory framework needs to become more flexible in order to address the technical challenges involved.
“In this case, the state needs to have — and it is very good that it does have — strategic control over this resource, which is probably the most important resource we have. But it also needs to be more flexible and take into account the fact that it is dealing with technical issues that are extremely difficult to solve. We cannot wait any longer,” he said.
Amato described floating solar as a relatively small but increasingly important segment of the renewable energy market.
“Floating is a small but extremely important niche. Floating PV on its own is not a greater challenge than a ground-mounted photovoltaic park. It is already a proven technology. It started in 2007, and there are plants that were installed on water almost 20 years ago and are operating well,” he said.
The greater opportunity, according to Amato, lies in combining floating solar with existing hydropower infrastructure and battery storage.
“The idea becomes interesting when we manage to hybridize hydroelectric resources with solar resources and, together with them, batteries,” he said.
“This synergy allows not only an increase in energy production, because a photovoltaic park is added, but also better and more flexible management of the water resources,” Amato added.
Battery storage could also help reduce the operational stress on hydropower equipment while providing additional flexibility to the electricity system.
“Batteries are extremely important and will also allow for less wear and tear on the generating units when responding to grid regulation requirements,” he said.
“There is this possibility of hybridization, and Romania has a very large asset base in this respect. From a hydropower perspective, I believe more difficult periods are ahead. We understand that water flows will decrease, and therefore I believe there will be growing interest in floating photovoltaic parks,” he said.
Since 2004, ‘The Diplomat – Bucharest’ aims to bring a fair and balanced analysis and comprehensive coverage of the political and business scene in Romania.
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London Borough of Islington
2023-2024
Economics, Energy consulting
The strategy focused on helping the borough identify the most effective ways to support local businesses in cutting costs by installing rooftop solar panels, with funding provided wholly or partially by the council.
The project was delivered as a feasibility study, providing Islington Council with an evidence base, delivery options and strategic recommendations to support future decision-making around borough-wide solar deployment. While the scheme did not progress to implementation at that stage, the work has helped inform the council’s ongoing approach to solar rollout.
The project methodology included a screening assessment to identify suitable commercial building roof spaces, stakeholder engagement activities, a techno-economic model used to assess the viability of different scheme design options including calculation of socio-economic benefits and carbon reduction impacts. The outcome was the prioritised list of viable deployment scenarios and sites that the local authority could then use to approach owners.
The screening and prioritisation process would need to consider scheme size, yield, potential off-take arrangement and scheme financial return (balancing value both to local businesses and the local authority).
Initial challenges such as mapping approach, setting criteria and KPIs for selection, and performing a thorough techno-economic evaluation were addressed. Both technical and commercial aspects were overseen, ensuring the project aligned with the client’s goals and supported a just transition for the community.
These efforts established a robust evidence base and delivery model that could support future solar deployment initiatives for the council and local businesses.
Two stakeholder engagement exercises were undertaken. The first, was a business survey to map existing energy supply characteristics and gauge interest in the scheme, and a second was a workshop designed to capture local businesses’ opinions and requirements for participation.
Site analysis was conducted along with PV array sizing, energy balance assessments, and the development of a techno-economic model to evaluate feasibility. Additionally, socio-economic and carbon impacts were assessed to support the business case.
To enable the mapping of the properties within the borough, a Geographical Information System (GIS) was used. The GIS software captured all commercial properties that had been selected based on agreed criteria. The tool kit was then used to calculate the potential array sizes for each of the buildings.
The potential array size was calculated using the available rooftop area and this was coupled with the LiDAR data to calculate the solar irradiance levels.
Energy use in buildings and PV generation are both transient as they can vary depending on factors such as time of day, weather, location, building type and working practices. In our study we highlighted how the energy balance of the system works and includes aspects such as annual consumption, annual generation, alongside energy imports and exports.
We also developed the considerations that form the business case for the Islington solar scheme split into considerations around ownership, procurement, energy sales, carbon accounting and socio-economic impacts. Our experts developed a techno-economic model, using the annual yield of the systems coupled with their capital expenditure costs, operation and replacement costs over the system’s lifespan. The modelling then calculated the cash flow for the project considering investment interest payable over the loan term and establishing the payback period for the project. A version of the TEM was delivered to the client to allow the local authority to also undertake its own assessment and adjust parameters.
We created a tool to analyse 1,198 non-council rooftops for ~25MWp solar potential in Islington, to support the development of an effective business plan that highlights savings and revenue opportunities for the local authority, while benefiting the community and building climate resilience and adaptation.
The stakeholder engagement provided valuable insight into the community’s perspectives. The business community responded positively to the proposals. Further analysis would need to determine how much of a discount on the energy bill would be required to attract building owners to participate in the scheme. The levels of discount provided by the council to local building owners will need to balance commercial viability and consumer attractiveness for the scheme.
Although the project was delivered as a feasibility study rather than progressing immediately to implementation, it provided the council with a robust evidence base, a detailed understanding of borough-wide solar potential, and clear strategic recommendations that continue to inform future renewable energy initiatives and solar rollout planning.
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Newswise — Switching to modern silicon solar cells could help the cost of powering satellites fall by as much as 90 per cent based on beginning-of-life (BOL) performance, according to a review led by the University of Surrey. The switch to silicon cells could also halve the weight of the solar cells needed on the spacecraft, freeing mass for fuel or instruments, or cutting launch costs.
Silicon was the industry-standard solar cell material for spacecraft from 1958 until 1977, when gallium arsenide cells displaced it, offering better efficiency and radiation resistance. Triple-junction cells built from gallium, indium and germanium have been the standard ever since.
Today, silicon heterostructure cells hold a record efficiency level of 27.8 per cent and perovskite/silicon tandem cells hold a record of 34.85 per cent.
In a review published in Acta Astronautica, researchers from Surrey show that triple-junction space cells cost between $250 and $450 per watt, whereas silicon costs tens of cents. As of November 2025, the three main silicon designs (PERC, TOPCon and heterojunction) averaged $0.275, $0.285 and $0.39 per watt respectively.
The raw materials are cheaper too: silicon costs a few dollars per kilogram, while gallium and germanium cost thousands per kilogram.
To make this more tangible for real-world usage, the team from Surrey modelled two formats – one face of a 3U CubeSat (a satellite roughly the size of a large loaf) and a Micro Sat built by Surrey Satellite Technology Limited (SSTL), which co-funds the lead author’s PhD and supplied the spacecraft data used in the study. Including the space-qualified glass that protects the cells, the saving was as large as 85 to 90 per cent.
Coverglass, not the cell, dominates the cost of a silicon array.
Tommy Richards, lead author and postgraduate researcher at the University of Surrey’s Advanced Technology Institute, said:
“The interesting finding for us was not that silicon is cheaper but where the remaining cost sits. Once you put silicon cells behind space-qualified glass, the glass is what you are paying for.
“That changes what we should be working on. If we can make the cell itself tougher against radiation, we can use thinner glass or substrates, and we cut cost and weight at the same time. It reframes the problem from a materials contest into an engineering one we know how to attack.”
In the review, silicon heterojunction cells delivered roughly twice the specific power of the triple-junction option, at around 920 to 1,000 watts per kilogram against 455 to 505. In simple terms, a mission could carry half the solar cell mass for the same power output.
Silicon does produce less power for a given area, and the review puts the reduction at around 28 per cent at the start of a mission. But when the researchers scaled the panels to match triple-junction output, including the cost of the extra panel structure, silicon remained several times cheaper on BOL performance.
However, silicon is not the winner on every measure. For a given coverglass thickness, silicon is around 2.6 times less resistant to radiation than triple-junction cells. Triple-junction cells are also expected to retain more of their performance after five years in orbit, which highlights the importance of improving the radiation resistance of silicon devices.
The number of objects launched each year has risen from around 120 in 2010 to more than 2,800 in 2024. An average satellite needs close to a kilowatt. Proposed space-based solar power stations, which would collect sunlight in orbit and beam it to Earth as microwaves, could require structures kilometres across, delivering gigawatts. The review argues that demand on that scale would consume the entire triple-junction market but barely register against silicon output.
Professor Ravi Silva CBE FREng, Director of the Advanced Technology Institute at the University of Surrey, said:
“We really need to start looking at satellites as infrastructure now. Weather forecasts, navigation, broadband, crop monitoring and disaster response all run through them. Anything that makes a satellite cheaper to build and lighter to launch widens who gets to use that infrastructure, and that includes smaller nations, universities and start-ups rather than only the largest agencies and operators.
“And if we are serious about collecting solar power in orbit and sending it home, we will need solar cells on a scale the specialist space industry simply cannot produce. Silicon is the only material with factories already running at that size. The technology on rooftops and in solar farms could turn out to be the technology that powers the next generation of spacecraft.”
The review identifies ultraviolet (UV) light as the least understood risk for bare devices. Modern silicon architectures degrade under UV exposure, and heterojunction cells, the best performers on efficiency, degrade more than PERC cells. Almost all testing so far has used UVA, the lower-energy ultraviolet that reaches the Earth’s surface, rather than the more energetic vacuum ultraviolet found in space.
Dr Jae Sung Yun, corresponding author from the University of Surrey’s Advanced Technology Institute, said:
“If we are going to collect solar power in orbit and send it back to Earth, we will need solar cells by the square kilometre. Silicon is the one material we already know how to make on that scale, and it is the one we can afford to make that much of.”
The review sets out the areas the authors believe need attention: testing modern cells under the high-energy ultraviolet found in space, testing them across the temperature swings of a real orbit and testing them for radiation while they generate power. It also revisits older ideas worth another look, including lithium doping, an approach first reported in 1966 that allowed cells to repair their own radiation damage, but which was later set aside.
https://www.sciencedirect.com/science/article/abs/pii/S0094576526003644?via%3Dihub
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Edinburgh graduate-founded solar technology company SolarSub has secured £1.34 million to develop and commercialise its passive cooling technology for solar panels.
The UK start-up will use the funding to accelerate technical development, testing and commercial deployment of a system designed to keep photovoltaic panels cooler during operation.
SolarSub’s technology contains no pumps or moving parts and is designed to keep panels closer to their optimal operating temperature, increasing energy output and reducing heat-related degradation.
The funding round was led by Sustainable Ventures, with investment from Zinc VC, Scottish Enterprise, Old College Capital, SFC Capital and the British Business Bank. Additional support came through Innovate UK’s Investor Partnership programme.
SolarSub’s founders are engineering graduates of the University of Edinburgh, with the company’s technology originating from research carried out at the university.
Early trials have recorded energy gains of up to 17.5% at the University of Edinburgh’s FloWave ocean energy research facility.
Outdoor testing at Heriot-Watt University’s Dubai campus recorded peak improvements of up to 19%.
The new investment will fund further product development, independent testing and real-world deployments with research, utility and industrial partners.
SolarSub also plans to expand its engineering team and prepare the technology for manufacture, certification and commercial rollout.
Read more
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Sebastiaan Schalkwijk, CEO and co-founder of SolarSub said: “I’d like to thank all of our investors and supporters for backing us as we move into the next stage of SolarSub’s development.
“It’s been great to see the technology progress from the early days of research at the University of Edinburgh to the point where we’re now preparing for larger-scale trials and commercial deployment.”
James Taylor, co-founder and chief operating officer of SolarSub said: “I am immensely proud of the team in getting to this point.
“This investment allows us to move from successful technical validation into the next stage of real-world deployment.
“Our focus will now shift to demonstrating the technology at increasing scale and building out our commercial adoption with industry partners.”
Joshua Armistead-Wood, investor at Sustainable Ventures said: “The challenge of energy generation is one that, unsurprisingly, remains at the top of our agenda, particularly at a time of increasing price volatility.
“The solution the SolarSub team is developing stood out to us because, instead of trying to reinvent the wheel, they are focused on one simple root of inefficiency within existing solar systems: excess heat.
“We have been impressed by what the team has achieved to date and are excited to work with them as they deliver the next stage.”
Derek Shaw, director of company funding and investment at Scottish Enterprise said: “Our investment in SolarSub Ltd underscores our commitment to creating an internationally competitive energy transition industry in Scotland.
“By supporting ambitious companies in areas such as clean energy technology, we can help them drive innovation and capitalise on the significant economic opportunities linked to the shift from the production and consumption of fossil fuels to sources of renewable energy.”
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Abu Dhabi’s utility, Emirates Water and Electricity (EWEC), is targeting more than 35GW of solar capacity by 2035.
The utility has set an interim target of 14GW of PV by 2030, up from an earlier target of 10GW, as it scales its installed capacity to beyond 35GW by the middle of the next decade.
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The planned PV deployment will be backed by 15GW of battery storage capacity, enabling ‘round-the-clock’ provision of solar-generated power.
The UAE has set increasingly ambitious renewable energy targets as it capitalises on its abundant solar resources, which make it one of the lowest-cost regions for PV-generated electricity worldwide.
Last month, state-run media reported comments from the Emirati energy minister that the UAE overall was aiming for renewables and nuclear energy generation to account for 35% of its energy mix by 2030-31.
In this latest statement of intent, Mohamed Almarzooqi, chief assets officer of EWEC, said: “We are actively procuring the utility-scale solar photovoltaic, battery storage and reverse osmosis desalination capacity required to deliver this outcome, structurally reducing the reliance of the system on gas-fired generation. Through this transformation, EWEC is enabling the UAE and Abu Dhabi to build a highly diversified, resilient, and low-carbon system that seamlessly meets rising demand while strengthening water and energy security.”
No further details were provided on how the solar targets will be met, but Abu Dhabi is already working on several solar and storage mega projects. These include a 5.2GW/19GWh round-the-clock solar-plus-storage facility that reached financial close in July and the 1.5GW Khazna solar plant, which also completed financing earlier this year. It is already home to the 1.2GW Noor solar power plant (pictured), one of the world’s largest standalone PV power plants.
EWEC said it was forecasting that carbon emissions from its power and water production would fall by over 45% by 2035, even as annual electricity demand is forecast to rise by around 70% 2026 and 2033.
The government of Albert is introducing a new recycling system for end-of-life solar panels.
Beginning October 1, the province will apply an environmental fee of CAN 14 to each new solar panel supplied in Alberta. The fee will not be applied retroactively to already-installed panels.
According to details on the government’s website, a typical residential installation of 20 panels would raise a fee of CAN 280, equivalent to less than 1.5% of the overall installation cost.
The fee will go towards ensuring money is available to collect, transport and recycle panels once they reach end of life. The provincial government has committed to working with the Alberta Recycling Management Authority and wider industry to build reuse and recycling capacity in Alberta as volumes of recycled panels increase.
Additional figures on the government’s website says Alberta has the second-largest installed solar capacity in Canada, with 95% of currently-installed panels expected to reach their end of life by 2045, generating as much as 72,700 tonnes of material.
The province says its solar panel recycling program is the first of its kind in North America.
Grant Hunter, Alberta’s Minister of Environment and Protected Areas, said the region is putting the system in place now to recover valuable materials, attract private investment and build a new recycling industry here in Alberta.
“Alberta has never been afraid to lead,” Hunter said. “We will not wait until mountains of dead solar panels are piling up in our landfills before acting.”
RJ Sigurdson, Alberta’s Minister of Affordability and Utilities, added that the program will protect taxpayers from future clean up costs.
Writing on LinkedIn, Radha Rajagopalan, Director of Policy for Alberta at the Canadian Renewable Energy Association, noted that the CAN 14 fee is more than five times the highest fee charged under Alberta’s electronics recycling program and more than three times the cost indicated by the association’s independent analysis.
“Alberta needs stable, predictable policy to attract investment and build the affordable, reliable electricity the province needs,” Rajagopalan commented. “Adding unnecessary costs to new renewable energy projects sends the wrong signal at a time when Alberta needs more electricity in the system.”
Alberta’s latest update says it is also ruling out solar panels being sent to landfill sites across the province. Research published earlier this year found recycling a utility-scale solar module in the United States currently costs between $15 and $45, while sending it to landfill costs between $1 and $5.
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EWEC says it is actively scaling Abu Dhabi’s solar capacity to more than 35 GW of solar capacity by 2035
It will also target up to 15 GW of battery storage to support the expanding solar fleet
The planned power and water system changes are expected to cut emissions by more than 45% by 2035
Emirates Water and Electricity Company (EWEC), solar electricity and water supplier in Abu Dhabi, plans to expand its cumulative solar capacity to more than 35 GW by 2035, alongside up to 15 GW of battery storage.
As Abu Dhabi prepares to meet rising electricity demand, EWEC has raised its solar target to 14 GW by 2030 and more than 35 GW by 2035, compared with its earlier targets of 10 GW and 18 GW, respectively.
The company said the strategy supports the Abu Dhabi Department of Energy’s Clean Energy Strategic Target 2035 and the UAE’s Net Zero by 2050 strategy.
The planned expansion, it explains, will support a more than 45% reduction in carbon emissions from power and water production targeted by 2035.
“EWEC’s strategic planning ensures that our water and energy infrastructure expands substantially to power economic growth, even as total carbon emissions significantly decline,” said Mohamed Almarzooqi, Chief Assets Officer of EWEC.
EWEC said gas generation will continue to provide flexibility for variable renewable power in the near term, although its contribution is expected to decline as solar and storage capacity expands.
“We are actively procuring the utility-scale solar photovoltaic, battery storage and reverse osmosis desalination capacity required to deliver this outcome, structurally reducing the reliance of the system on gas-fired generation,” added Almarzooqi.
Among EWEC’s planned solar and storage projects is a 5.2 GW solar PV and 19 GWh battery storage project, described as the world’s first gigascale renewable energy project designed to deliver power around the clock (see UAE To Host World’s ‘1st’ Facility To Provide RE 24×7, At Scale).
Earlier this year in May 2026, EWEC partnered Masdar to deploy over 30 GW of solar PV and over 8 GW of battery storage capacity in the UAE (see Masdar & EWEC Partner For 30 GW Solar & 8 GW Battery Storage).
TaiyangNews 2024
Scientists found a much cheaper way to measure how well solar panels perform digitaltrends.com
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Solar PV supplied roughly three-quarters of new renewable capacity added globally in 2025, according to a new IRENA report
Battery storage additions rose sharply last year as renewable generation expanded
It calls for accelerated grid expansion and flexibility to integrate the next wave of solar and storage
Global renewable energy capacity reached another record in 2025 with 693 GW, led by solar PV, but deployment still needs to accelerate significantly to meet the 11.2 TW goal for 2030 under the UAE Consensus, says a new report. The world’s cumulative installed renewable energy capacity reached 5.15 TW at the end of 2025.
Released by the International Renewable Energy Agency (IRENA), the COP31 Presidency and the Global Renewables Alliance, the report said 693 GW of renewable power capacity added in 2025 represents 15.5% annual growth.
However, the pace still falls short of what is needed to meet the UAE Consensus target of 11.2 TW of global renewable capacity by 2030. IRENA now estimates that an average of 1.204 TW of renewable capacity must be added annually between 2026 and 2030. This is higher than the 1.122 TW annual average it estimated in October 2025, when the calculation covered 2025 through 2030 (see World Must Add 1.12 TW Renewables/Year To Meet COP28 Goal).
Solar PV accounted for the largest share of new renewable capacity in 2025. IRENA counts about 513 GW of solar PV deployment last year, representing around three-quarters of all new renewable capacity and 12% more than in 2024.
Co-located solar and storage accounted for about one-quarter of utility-scale solar capacity commissioned globally in 2025, says the report citing Bloomberg New Energy Finance. It links the trend partly to falling daytime electricity prices and rising curtailment in some markets.
By the end of 2025, solar PV represented 46.3% of global installed renewable capacity, with 2,388 GW installed worldwide.
IRENA said solar capacity will need to double during 2026-2030 compared with the 2025 level to remain aligned with the 2030 objective.
While solar’s relatively short permitting timelines, established supply chain and cost competitiveness support further deployment, the report writer call for policy frameworks to evolve alongside the pace of solar expansion.
Solar was also among the lowest-cost sources of new electricity in 2025. IRENA put the global weighted average levelized cost of electricity (LCOE) of solar PV at $44/MWh, compared with $33/MWh for onshore wind. Excluding China, the average solar PV LCOE was $55/MWh, and $51/MWh for onshore wind.
Storage becomes increasingly important
Battery storage is also expanding as renewable generation grows. Around 112 GW, or about 307 GWh, of battery storage capacity was added globally in 2025, up 48% from 76 GW added in 2024, according to the report.
China accounted for 61 GW of the additions, followed by the US with 18 GW and Europe with 16 GW. Together, these three markets represented nearly 85% of annual battery storage additions at the end of 2025.
IRENA said storage can absorb surplus renewable electricity and discharge it when needed, while also supporting grid stability and reducing congestion. Falling costs are strengthening the economic case for storage, it added.
The report said the cost of a fully installed and commissioned battery storage project declined by almost 30% between 2024 and 2025. Since 2010, costs have fallen by about 95%, from $2,634/kWh to $140/kWh.
Solar-plus-storage gains ground
The report also highlights the growing role of solar paired with storage as the costs of firm, around-the-clock renewable energy generation begin to undercut new gas-fired alternatives. At high-quality sites, the report claims the LCOE of solar-plus-storage at 95% reliability fell to $54-$82/MWh in 2025, down from more than $100/MWh in 2020. IRENA expects the cost to fall by another 30% by 2030 and 40% by 2035.
Grids remain a constraint
IRENA said faster renewable and storage deployment will need to be matched by investment in electricity grids and system flexibility. Grid expansion and modernization have not kept pace with renewable deployment, it added, contributing to connection queues and increasing pressure on infrastructure.
The report recommends regulatory frameworks that allow storage to be co-located with solar and wind, including shared grid connections. It also calls for incentives for storage alongside demand response, interconnections and other flexibility resources.
The report concludes that the 2030 renewable capacity target remains within reach only with a significant increase in annual deployment, supported by investment, infrastructure, policy frameworks, supply chains and skills.
The complete report titled Delivering on the UAE Consensus: Tracking progress toward tripling renewable energy capacity and doubling energy efficiency by 2030, is available for free download on IRENA’s website.
TaiyangNews 2024
Cumulative solar photovoltaic (PV) manufacturing capital expenditure (capex) in the United States, since the introduction of the Inflation Reduction Act in 2022, is forecast to reach $12.2 billion by the end of 2026, accounting more than 50% of all solar PV manufacturing spending since 2001.
This analysis is taken directly from the new Solar Manufacturing USA Quarterly report, released today by Terawatt PV Research – with the research undertaken by the company’s founder and author of this article, drawing on experience of scrutinizing the operations of more than 500 solar PV manufacturers globally since the solar industry moved from R&D to commercial status more than two decades ago.
The new U.S.-specific report returns to the fundamental building-blocks required to understand key quarterly metrics at individual PV manufacturing sites: effective ramped capacity, production output, technology segmentation and manufacturing capex.
Moreover, for the first time, the depth of coverage on PV manufacturing capex has been extended beyond simply equipment-spending at the company level.
The new analysis now segments PV manufacturing capex at the quarterly level for individual manufacturing sites in the United States and further splits the company/site/value-chain/technology-specific manufacturing capex across buildings/infrastructure, new production equipment and maintenance/upgrades.
The net result is unprecedented visibility on the U.S. solar manufacturing sector and the individual companies currently in production, building/equipping new PV factories or adding capacity within existing operating sites.
Furthermore, the consolidated totals provide a highly accurate picture of the entire domestic solar PV manufacturing landscape in the United States today, allowing forecasting out to 2030 to be undertaken with greater levels of confidence.
The new report focuses on company-specific manufacturing sites in production since 2020, leading into the Inflation Reduction Act in 2022, the subsequent uptick in manufacturing capex from 2023 until today, and bottom-up forecasting out to the end of 2030 factoring in the impact of new investments arising from Section 232.
In reviewing the consolidated totals, solar PV manufacturing capex since the Inflation Reduction Act was introduced has been a gamechanger for the domestic U.S. PV manufacturing sector.
U.S. solar PV manufacturing capex has exceeded $2.5 billion each year since 2023. A record $4.14 billion was spent on PV manufacturing capex in the United States during 2024, with more than 60% coming that year from just two companies – First Solar (mainly through its spending on new factories in Alabama and Louisiana), and Qcells (part of Hanwha Solutions) from its vertically-integrated investments in Georgia.
Segmenting U.S. manufacturing capex now across buildings/infrastructure, new production equipment and maintenance/upgrades reveals some important dynamics at play for domestic PV production sites today, with the allocations to buildings/infrastructure varying strongly between refitting an existing warehouse for module assembly to building a dedicated greenfield site for solar cell manufacturing (by more than an order of magnitude on a per-installed-Watt basis).
Figure 1: Solar PV manufacturing capital expenditure has grown significantly since the introduction of the Inflation Reduction Act at the end of 2022, with factory build-out spending from buildings/infrastructure costs accounting for about 60% of the total spend during the 2023-2026 period.
For more than 20 years, analyzing the details behind PV manufacturing capex injected into the global solar industry has been pivotal in understanding how new capacity or upgrade-spending are ramped into production; and how the announced capacities translate into production volumes at any given time.
The specifics behind how solar PV manufacturing capex was spent across Japan, Taiwan, South Korea, India, China and Southeast Asia during 1990-2024 played a key part in the evolution of global PV manufacturing and technology during this high-growth sector phase; not to forget the manufacturing capex into thin-film technologies in the United States 15-20 years ago that had very different consequences.
Capex, capacity and production should not be difficult metrics to understand. Yet almost daily, there are misleading discussions about ‘capacity-mismatches’ through the value-chain, over-capacity ‘concerns’, and even some observers talking about the U.S. having to become an ‘exporter of solar modules’, something that has not happened since the 1990’s.
At its core, market research is about tracking capex, technology, production, shipments, pricing, costs and margins at the company and manufacturing site level. Capacity is really an issue only when forecasting production volumes in the future.
In its simplest form, production is in fact the ‘actual’ capacity of a factory at any given time. The ‘effective installed capacity’ is the maximum output of the site based on 24/7 operations and 100% yield.
Thereafter, the relationship between production and capacity is not ‘utilization’ but ‘effective capacity conversion’ and this is determined by production-line uptimes and how many shifts are being operated.
Figure 2: Effective capacity levels for c-Si cells and modules in the United States have been growing quarter-on-quarter since the start of 2025, with effective-capacity-conversion rates varying considerably at the manufacturing site level, from figures of 15-20% during early ramp-up to 70-80% from a select group of companies only. Forecasting cell and module production volumes out to 2030 ultimately frames the additional upstream capex needed to create a more balanced value-chain for silicon-based manufacturing in the United States.
Analyzing manufacturing metrics at the site level allows for regional trends to be quickly established. Looking at the production numbers here is particularly useful in assessing where materials supplies could be strategically developed.
Currently, this type of analysis can only be applied to module production in the United States. Doing this for ingots, wafer and cells is too early.
From a state-level perspective, Ohio – by virtue of First Solar manufacturing bases – was the dominant zone for module production volumes in the United States leading into the IRA being rolled out. However, Texas is the real winner in the post-IRA era, becoming the state leader in module production in 2026 with meaningful contributions from Canadian Solar, Sirius/Elin, Imperial Star, SEG Solar, T1 Energy, TOYO/Abalance and Waaree Energies.
Elsewhere, much of the action is in the Southeast of the country, with a logical geographic split here in grouping the gulf coast corridor of Louisiana and Florida and the advanced manufacturing region including the Carolinas, Georgia and Alabama.
Figure 3: Solar module production in the United States shows strong state-level and regional bias, with Texas emerging now as the major hub for c-Si module assembly, with leading proponents such as Canadian Solar, SEG Solar and T1 Energy.
The final output of the new report is to rank and rate the companies analyzed individually in the report.
This step is essential to allow greater emphasis to be placed on tracking the manufacturing decisions taken by the top 20 companies in the U.S. solar sector at any time, given that this subset of companies is typically accounting for more than 95% of all investment and production of significance.
Let’s walk through the methodology now to explain exactly how this is done.
As discussed earlier, the report is built from a newly created, proprietary, bottom-up database of U.S. solar manufacturing activity, analyzed at the individual manufacturing-site level by quarter.
Production is tracked across the c-Si value-chain from polysilicon through modules, together with segmented thin-film ‘cell’ and ‘module’ output equivalence.
Capex is further segmented between buildings and infrastructure, production equipment, and maintenance and upgrades; while excluding R&D contributions to capex.
The underlying data draws on audited filings and company reporting where available, supplemented by bespoke market research analysis based on additional operational and industry evidence and personal communications.
This approach allows current manufacturing activity (production) and the strongest leading indicator of future production growth – capital investment in manufacturing, or ‘manufacturing capex’ – to be assessed within a consistent analytical framework.
Production and capex are independently subjected to statistical transformation and normalization before being combined through a weighted methodology to generate a Manufacturing Strength score for each company.
An operating-production screening process prevents companies with little or no realized production output from being elevated solely by announced or early-stage capital spending.
The resulting scores determine company rankings, while a standardized Z-score analysis measures each qualifying manufacturer relative to the wider U.S. peer-group distribution and forms the basis of the AAA-to-C Manufacturing Strength ratings presented in the report’s ratings hierarchy which is logically presented visually as a truncated pyramid.
Ratings are displayed on an annual basis, with each quarterly report updating the underlying production and capex assumptions — and therefore the forecasted full-year ranking and rating — as new evidence emerges.
The methodology is summarized in the process-flow chart below, which shows how the underlying site-level data architecture feeds into the two core inputs of Production and Capex, how these are independently processed and combined, and how the resulting Manufacturing Strength scores are converted into company Rankings and Ratings.
The first Manufacturing Strength Ratings Pyramid for U.S. solar PV manufacturers will be revealed during my opening talk at the Solar Manufacturing USA 2026 conference in Austin, Texas on 22-23 September 2026.
Figure 4: Manufacturing Strength ratings flowchart showing how site-level production and capex data are statistically processed, combined and converted into company rankings and annual AAA–C ratings for all solar PV manufacturers in the United States today.
The Terawatt PV Research Solar Manufacturing USA Quarterly report is released today, with the first quarterly deliverable scheduled for the start of October 2026, when the analysis for Q3 2026 is completed.
All report enquiries and subscriptions are being managed exclusively by pv magazine USA, extending the working partnership between the parties that led to the launch of the Solar Manufacturing USA event in 2026.
To register your interest in the report, please send an email to: [email protected]
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Researchers from the University of Stuttgart, the Research Center Jülich, and Solarzentrum Stuttgart have come up with a way to check the efficiency of solar cells — with nothing more than a lightly-modified off-the-shelf consumer-grade digital camera.
"An electroluminescence image contains much more quantitative information than simply showing bright and dark regions," explains co-author Jürgen Werner of the team's work. "With a suitable physical camera model and calibration, it can provide absolute luminescent quantum efficiency and, therefore, information about the local quality of a solar cell or module. Our approach shows that even a relatively inexpensive consumer camera can provide quantitative results when its physical response is properly modeled and calibrated."
Quantifying the efficiency of solar cell, whether it's straight off the factory floor or has been installed in-the-field for some time, can already be done by testing the cell's luminescent quantum efficiency — but it requires extremely expensive lab-grade camera systems. The team's contribution to the field is a way to modify cheap off-the-shelf consumer-grade cameras to capture the same information by removing the camera's usual internal infrared filter and replacing it with an external long-pass filter.
The result: a camera that can see in the infrared. It's a technique that has long been used by photographers to capture otherworldly images, but combined with careful measurement of the camera's capabilities means that it can be used to replace expensive lab equipment — making luminescent quantum efficiency measurement within the reach of more people.
"Our next step is to use the calibrated camera to determine quantum efficiencies and open-circuit voltages of further, previously uncharacterized solar cells and modules," Werner adds. "The same model should also be applicable to photoluminescence measurements and potentially to measurements performed in daylight."
The team's work has been published in The Journal of Applied Physics.
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Perovskite PV manufacturer, GCL Perovskite, has completed an end-to-end production run on its GW-scale perovskite module manufacturing line, covering the entire process from raw-material intake to the production of large-area modules. The company said commercial module deliveries are gradually increasing as its focus shifts to production stabilization and yield ramp-up. Current priorities include improving equipment stability during continuous operation, overall line yield, and material utilization while reducing unit manufacturing costs. GCL Perovskite added that its 2 m² single-junction perovskite module has received third-party certification of IEC 61215, while its perovskite-crystalline silicon tandem module has received both IEC 61215 and IEC 61730 certifications. In another development last year, GCL Perovskite led space PV module standard drafting (see China Solar PV News Snippets)
In a technology upgrade, JinkoSolar plans to invest RMB1.792 billion in its Yuanhua base in Haining, Zhejiang province. The project will retire older equipment including texturing machines and tabber-stringers, and introduce advanced wet-processing and patterning equipment, and deploy digital systems including MES, SAP and AI-based tools. According to publicly disclosed environmental impact assessment materials, the project will retire the site’s existing 6 GW crystalline silicon cells and 6 GW modules, while retaining the cell R&D functions. Following the upgrade, the facility plans to have an annual production capacity of 2.7 GW of high-efficiency “new-structure” cells and 4 GW modules. The publicly disclosed EIA materials do not explicitly identify the technology that will be used for the new cells.
Battery manufacturer, CBAK Energy, has disclosed internal test results for its 32140 NH-7Ah full-tab sodium-ion cell and outlined a conditional long-term plan for 12 GWh of annual sodium-ion battery production capacity. The planned lines will be designed to support both sodium-ion and lithium-ion cell production. The company said its NFPP cell reached 90% charge within 15 minutes, while capacity retention remained above 95% during continuous discharge at 15C. At -40°C, the cell retained 87.68% of its discharge capacity relative to its 25°C baseline. Based on internal cycle-life testing and trend analysis, CBAK Energy projects at least 10,000 life cycles under specified protocols. Customer testing of samples is underway in residential and portable energy storage systems, and two and three electric wheelers, while additional evaluations cover backup power and other applications.
EVE Energy has signed a strategic cooperation agreement with China Railway Beijing Engineering Group Co., Ltd., a subsidiary of China Railway Group, with the two companies agreeing on at least 5 GWh of energy storage project over the next three years. The partnership will focus on new energy projects, energy storage applications and coordination in infrastructure development, supported by a dedicated working mechanism. China Railway Beijing Engineering Group is active in infrastructure, power, solar and EPC projects, while EVE Energy supplies energy storage cells and integrated storage systems. The companies plan to combine their engineering and storage equipment capabilities to advance related projects.
Energy China has launched its 2026 centralized procurement for PV modules, with an estimated volume of 15 GWp across 6 packages, covering EPC and self-invested projects. This year’s procurement is 2 GW smaller than its 17 GW procurement of 2025 with 8 packages. Covering TOPCon, HJT and BC module technologies, the bids are due by October 9, 2026. Here are more details:
For the two TOPCon packages, bidders must have at least 2.5 GWp of cumulative sales over the previous three years from individual contracts of 10 MWp or more.
Package 4 additionally requires at least four individual TOPCon contracts of 100 MWp or more.
The HJT packages require at least 150 MWp of cumulative sales over the same period, while the BC packages require at least 1.5 GWp of cumulative module sales across all technology types.
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Apex starts work on battery storage plant next to solar farm Belleville News-Democrat
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The Los Angeles City Fire Department (LAFD) has concluded its investigation into the June 17 fire at a Lineage cold storage warehouse in Boyle Heights, classifying the cause as undetermined.
Investigators confirmed that the weeklong fire originated on the roof, at or adjacent to a section of solar panels. The warehouse had 12,400 solar panels installed across the roof. The investigation did not identify discarded smoking materials, intentional devices, or other accidental ignition sources.
“Based on the evidence examined, investigators determined that an electrical event occurred within the area of origin. However, since the specific cause of that electrical event could not be conclusively established, the incident remains classified as having an undetermined cause,” LAFD said.
The investigation did not conclusively identify the solar panels or associated components as the cause, but could not rule them out.
Lineage has maintained that the fire began while contractors were working on solar panels and has filed a lawsuit against solar company Altus Power and technical infrastructure contractor Pearce Services.
Following the LAFD report, Lineage said: “Today’s report from the Los Angeles Fire Department validates what we have known all along: This was a solar fire.”
Los Palos Street Operating, a subsidiary of Altus Power, disputed that interpretation, stating: “Lineage, unfortunately, continues to misinform the public: its statement today is in direct conflict with the Los Angeles Fire Department’s finding that the cause of the incident is ‘undetermined.'”
Lineage is seeking permits to rebuild the facility. The Los Angeles City Council had previously voted to prevent reconstruction permits from being issued until the LAFD investigation was completed.
Cleanup of the warehouse was completed on September 5, including the removal of 89 million pounds of spoiled food and demolition of the fire-damaged structure.
Frontpage photo: © Martin Helgemeir | Dreamstime
Source: cbsnews.com
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With the recent expansion of a solar array near the University of Toledo Medical Center, UToledo is more than doubling its capacity for solar energy production on Health Science Campus while creating opportunities for student learning and research.
The University will celebrate the completion of the project with a ribbon-cutting ceremony beginning at 10:30 a.m. Thursday, Sept. 24. The array is located along Main Technology Drive, and the ceremony is set to take place in the adjacent Parking Area 44E.
UToledo will celebrate the completion of a solar array expansion near UTMC with a ribbon-cutting ceremony at 10:30 a.m. Thursday. The array is located along Main Technology Drive, and the ceremony is set to take place in the adjacent Parking Area 44E.
“This project is an exciting, real-world demonstration of the importance of the groundbreaking advances being made at First Solar and the strong connection to our work at the Wright Center for Photovoltaics Innovation and Commercialization,” said Dr. Michael Heben, a Distinguished University Professor and the Helen and Harold McMaster Chair and Director of UToledo’s Wright Center for Photovoltaics Innovation and Commercialization.
“In addition to the economic and environmental benefits, this array serves as an educational asset for our science and engineering students, offering hands-on experience with commercial-scale renewable energy systems. I applaud the hard work done by the Student Green Fund, Michael Green, director of energy sustainability and energy efficiency at UToledo, Dr. Randy Ellingson, a Distinguished University Professor and Wright Center for Photovoltaics Endowed Professor, and our friends at First Solar for making this all happen.”
The original installation has generated more than 2.6 million kilowatt-hours of clean energy since it came online in late 2020. When combined with a reduction in peak electrical demand, this translates to a total economic impact of nearly $275,000.
The expansion increases the nameplate capacity of the array from 330 to 750 kilowatts, more than doubling its expected annual electrical production. This annual electrical production is now estimated at more than $70,000, in addition to peak-demand savings.
As a student-driven initiative that benefits from cutting-edge technology donated by First Solar, the project reflects the power of student leadership, community partnership and research excellence at UToledo.
The array is the flagship project of the Student Green Fund, a committee of undergraduate and graduate students that administers the voluntary $5 fee that students are assessed each semester in partnership with UToledo’s Office of Sustainability. The fund has supported numerous student-led initiatives since its establishment in 2017, including the installation of high-efficiency hand dryers in campus bathrooms and refillable water bottle stations in high-traffic buildings on Main Campus and Health Science Campus.
The Student Green Fund contributed $350,000 to cover the first-phase installation of the solar array and $530,000 to cover the second-phase expansion.
The array is also supported by First Solar, the solar technology giant with a significant footprint in Northwest Ohio and long-standing ties to UToledo. First Solar donated Series 5 modules for the first phase and now Series 6 Plus modules for the second-phase expansion.
First Solar specializes in a type of photovoltaic technology that utilizes cadmium telluride.
UToledo is a global leader in the research and development of cadmium telluride and other thin-film technologies. University physicists — including two who are credited among the most highly cited researchers in the world — routinely publish ground-breaking research that supports a broader distinction in materials science that positions UToledo among U.S. News & World Report‘s Best Global Universities.
“This solar array project has grown into a sustainable system that improves our campus utilities while supporting community electrical grid reliability,” said Michael Green, director of energy sustainability and energy efficiency at UToledo. “It would not have happened without the Student Green Fund and First Solar. As we evaluate third-phase expansion, I look forward to working together to further sustainable systems development at UToledo.”
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Swiss engineers installed 4,872 solar panels on the Muttsee dam in Switzerland’s Glarus Alps, 2,500 metres above sea level. The project has shown significant potential for generating electricity during the winter months. However, installing solar panels at such a high altitude comes with its own set of challenges and benefits. Scroll down to find out more.
Image credit: Lombardi.group
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India’s solar sector is confronting an unexpected shift: while photovoltaic modules are lasting longer than ever, they may be losing economic relevance much sooner.
For years, a 25-year performance warranty has been central to solar project economics. Developers typically assumed that once installed, a module would deliver steady output with gradual degradation over decades. But rapid advances in technology are beginning to challenge that assumption.
Industry experts now point to what is being described as a “solar shelf-life” problem where modules remain functional but are no longer the most efficient or cost-effective option for the same asset base.
This shift comes at a time when India’s solar market is expanding aggressively. The country’s installed solar capacity has crossed 160 GW, supported by policy interventions such as the PM Surya Ghar rooftop scheme and domestic manufacturing mandates under ALMM (Approved List of Models and Manufacturers). However, a mismatch persists: module manufacturing capacity has scaled up rapidly, while domestic cell production remains limited, affecting supply chains and pricing.
At the same time, technology cycles are accelerating. The industry has moved from multi-crystalline to mono-PERC and now toward n-type technologies such as TOPCon, with efficiencies reaching 22–24% globally. Bifacial modules, once considered premium, now dominate installations.
“The pace of change means developers are no longer comparing a module only to its past performance, but to what’s available in the market today,” said a senior analyst at a renewable energy consultancy. “A plant built five years ago may still be operating well, but it could be significantly underperforming compared to new installations.”
This has implications for both utility-scale and rooftop segments. In large solar parks, where land and grid infrastructure are already secured, replacing modules, a process known as repowering is becoming economically viable. With module prices having fallen by nearly 90–95% over the past decade, upgrading systems without rebuilding entire plants is increasingly feasible.
However, the equation is different for residential consumers. Despite the push from schemes like PM Surya Ghar, rooftop adoption still faces barriers including high upfront costs, limited financing options, and low consumer awareness. For households, replacing modules prematurely may not be financially attractive due to installation and labour costs.
Another emerging challenge is how developers assess long-term value. Traditionally, procurement decisions focused on cost per watt. But industry participants say the focus is shifting toward metrics such as levelised cost of electricity (LCOE), degradation rates, and energy yield.
“There is a growing realisation that the cheapest module is not necessarily the best investment,” said an EPC contractor involved in utility-scale projects. “Performance over time and compatibility with future upgrades are becoming critical.”
Yet, the rapid turnover of technology also introduces risks. Newer cell architectures, while more efficient, have limited long-term field data. Concerns around degradation, UV stability, and performance in India’s diverse climatic conditions remain areas of scrutiny.
There is also a downstream implication. If modules are replaced earlier than expected, India could face a surge in solar waste. The country currently lacks a robust ecosystem for large-scale recycling and reuse, a gap that could widen as installations grow.
Looking ahead, industry observers say solar projects may need to be designed not as static assets but as evolving platforms. Developers are beginning to consider “repowering readiness” ensuring that mounting structures, inverters, and grid connections can accommodate future upgrades.
The shift marks a broader transition in how solar assets are valued. The question is no longer just how long a module will last, but whether it will remain economically optimal over its lifetime.
As one analyst put it, “In today’s solar market, the risk is not that a module stops working, it’s that something better arrives much sooner.”
The Author of this article is – Dushyant Kumar, PV Quality Manager, AXITEC Energy India Pvt. Ltd, leading solar module manufacturer
The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine.
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Lightsource bp is seeking approval under the Australian government’s Environment Protection and Biodiversity Conservation (EPBC) Act to build the Narrogin East renewable energy project incorporating a 150 MW solar farm with 250 MW of wind generation and a 200 MW / 800 MWh battery energy storage system (BESS).
The estimated $800 million (USD 568.8 million) project is proposed for a 4,481-hectare site located about 8 km east of Narrogin in Western Australia’s south. The project footprint will encompass about 470 hectares of mostly cleared land, and will play host to about 246,000 PV modules, 35 wind turbines and a centralised BESS.
Lightsource bp said the project has been designed to leverage existing infrastructure and will seek to plug into the existing 220kV Western Power transmission line that crosses the site. Once operational, the facility is expected to generate power equivalent to the annual consumption of is about 133,000 homes, contributing significantly to regional and national energy goals.
“This is a significant investment in Western Australia’s renewable energy future, bringing local economic opportunities and contributing to Australia’s transition to low-carbon energy,” the developer said.
“By integrating wind, solar, and battery storage systems at a single site, the project will generate, capture and store renewable energy for use when it’s most needed, supporting reliable, low-carbon electricity.”
“The battery will enable the project to store surplus energy during times of high renewable output and release it during peak demand, improving grid stability and maximising the efficiency of all renewable assets on site.”
While no construction timeline has yet been provided, Lightsouce bp said it expects all required approvals to be determined by mid-2027, opening the way for the project to move towards construction.
The Narrogin East renewable energy precinct is part of a wave of large-scale renewable energy projects being developed near the Wheatbelt town.
Others include Ace Power’s approved Narrogin Solar Farm project that incorporates 200 MW of PV generation with a 200 MW / 400 MWh battery, and the 200 MW / 800 MWh Narrogin BESS project being developed by TagEnergy.
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The median price of solar photovoltaic modules imported into the United States has risen by more than 40% since tariffs were imposed under Section 232 by the administration of President Donald Trump in August, according to Anza. The data provider compared average prices for imported modules before the new Section 232 rules with prices for modules bought since 7 August that are expected to be delivered after 4 December, when the minimum import prices under the rules take effect.
Anza reported that the average price of a module imported to the US moved from US$0.27/W to US$0.38/W between those periods. Anza president Aaron Hall told PV Tech that tunnel oxide passivated contact modules averaged US$0.38/W, passivated emitter rear contact modules were priced at US$0.385/W, and heterojunction modules were at a low of US$0.39/W, though considerably higher prices have been reported.
Hall indicated that the industry had spent months preparing for possible Section 232 effects and that the sector is now in the most important procurement window. He noted that the 4 December date matters, but that module purchasing should be arranged well before it. According to Hall, the date may be the effective one, yet developers cannot treat it as the moment to make a procurement decision, because modules require time to ship and clear US Customs, and lower-cost supply available before the deadline is already tightening.
Separate Anza data also showed that quotes for module prices after 4 December are about 15% higher, which points to continued price increases beyond the start of December. Alongside the data, the company recommended that buyers give priority to purchasing from domestic manufacturers and seek components and products that can clear US Customs before 4 December.
The elevated prices in the US contrast with lower module prices in Europe. Figures from sun.stores pv.index showed that back contact, full black and monofacial TOPCon module prices all declined between July and August, while bifacial TOPCon modules recorded a month-on-month price increase.
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Researchers from the University of Stuttgart, Forschungszentrum Jülich, and German company Solarzentrum Stuttgart have modified a low-cost consumer digital camera to detect infrared radiation emitted by electrically biased silicon solar modules and measure their external quantum efficiency (EQE).
In PV devices, EQE describes how efficiently electrons passing through a solar cell are converted into emitted photons during electroluminescence. The parameter can be used to assess the radiative quality of a solar cell and determine its open-circuit voltage.
“Our approach shows that even a relatively inexpensive consumer camera can provide quantitative results when its physical response is properly modeled and calibrated,” lead researcher Jürgen Werner said. “An electroluminescence image contains much more quantitative information than simply showing bright and dark regions. With a suitable physical camera model and calibration, it can provide absolute luminescent quantum efficiency and, therefore, information about the local quality of a solar cell or module.”
The scientists explained that conventional digital cameras employ silicon-based complementary metal-oxide-semiconductor (CMOS) sensors that can detect both visible and near-infrared radiation, including part of the spectral range associated with electroluminescence (EL) from silicon PV devices. Consumer cameras, however, typically incorporate an infrared-cut filter that suppresses near-infrared radiation. This filter strongly attenuates the weak EL emission from silicon solar cells, limiting the use of unmodified consumer cameras for EL imaging and quantitative PV characterization.
The researchers used a Canon EOS 4000D camera and removed its infrared-blocking filter to increase its sensitivity to infrared radiation. They also used a Heliopan ES RG850 long-pass filter to block shorter-wavelength visible background radiation from reaching the sensor. The camera, originally designed for visible-light imaging between approximately 400 nm and 800 nm, uses a silicon CMOS detector. Its Bayer filters are sufficiently transparent around 1,120 nm to detect the luminescence signal emitted by silicon solar cells.
In addition to modifying the camera hardware, the researchers developed a calibration model that relates recorded image brightness to the absolute luminescence emission of the PV device. The model accounts for both the linear and nonlinear response regimes of the camera, enabling the researchers to convert measured brightness into absolute electroluminescent EQE.
The team tested the camera in EL measurements performed in darkness to minimize background radiation. The calibration established a conversion factor between the measured brightness response and absolute external EQE and required a reference cell or module with known electroluminescent EQE and open-circuit voltage.
According to the research team, the experiments revealed a clear relationship between the measured luminescence response, EQE, and open-circuit voltage. At room temperature, a tenfold increase in the luminescence-related response corresponded to an increase of approximately 60 mV in open-circuit voltage. For the higher-efficiency modules, results obtained from the camera’s linear and saturation regimes were reportedly in good agreement. Deviations observed for older, lower-efficiency modules were attributed primarily to differences in light trapping and photon escape probability.
“An electroluminescence image contains much more quantitative information than simply showing bright and dark regions,” said Werner. “With a suitable physical camera model and calibration, it can provide absolute luminescent quantum efficiency and, therefore, information about the local quality of a solar cell or module.”
The researchers presented the camera and calibration method in “New camera model for absolute quantum efficiency measurements from electroluminescence of solar cells or modules,” published in the Journal of Applied Physics.
“Our next step is to use the calibrated camera to determine quantum efficiencies and open-circuit voltages of further, previously uncharacterized solar cells and modules,” Werner added. “The same model should also be applicable to photoluminescence measurements and potentially to measurements performed in daylight.”
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Comstock Metals, a recycling solutions company, and its parent firm Comstock have begun operations at a solar panel recycling facility located in Silver Springs, Nevada, according to PV Tech.
The site is now running on a continuous basis, slightly more than a month after the company reported that its solar panel recycling system had been fully integrated and tested. At that time, Comstock indicated that every major processing stage had been connected and operated successfully, and that testing of the facility’s individual unit operations had been finished.
Comstock added that it will now increase output on its production platform to satisfy rising customer volume requirements. When the project obtained a lease for the Nevada site in 2024, it was announced that the facility would be capable of processing as much as 100,000 tonnes of decommissioned solar photovoltaic modules annually once fully ramped up.
According to the company, moving to non-stop production delivers an efficient, high-volume, zero-landfill solution that removes disposal-related environmental liabilities for its utility-scale solar customers, who would receive a certification confirming the end-of-life regulatory obligations of the recycled solar panels.
Fortunato Villamagna, President of Comstock Metals, commented that after focused preparation work with production supervisors and operating staff across four shift teams, the company has now successfully advanced to continuous operations.
The Nevada solar panel recycling facility will eventually be joined by another Comstock facility in Ohio. In June of this year, the company said it would set up a solar panel recycling plant, production facility and logistics hub in Cambridge, Ohio. The expansion is intended to scale up the company’s operations, lower logistics costs and enhance services for its expanding Midwest and Eastern customer base.
A third facility in Hanford, California is also in progress. In February of this year, Comstock received certification from the California Department of Toxic Substances Control to recycle universal waste and process photovoltaic modules at its California facility. That site is planned to serve as a collection and pre-processing hub before materials are sent to the Nevada facility for final recovery.
Corrado De Gasperis, CEO of Comstock, said that the company has methodically developed, deployed and tested its system and is now operating continuously. He expressed the view that the technical implementation hurdles and uncertainties tied to the first-time scaled deployment of its proprietary Solar Panel Recycling Production system have now been overcome, and that with demonstrable continuous production, the company’s focus has shifted to volume ramp.
The 45th edition of PV Tech Power examines in depth whether the photovoltaic industry is prepared for the approaching wave of decommissioning and recycling, looking at the development and prospects of solar photovoltaic recycling markets globally.
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