T1 Energy, a startup solar panel maker that says it is “bringing solar technology and know-how back to America,” is making a push to retain eligibility for some of the most generous U.S. tax benefits even as the Trump administration prepares to crack down on “green energy” businesses’ ties to China. T1 is certainly vulnerable to the looming crackdown: The company maintains business ties to a massive Chinese solar company that is led by a member of the Chinese Communist Party and subsidized by the Chinese government, according to financial disclosures reviewed by the Washington Free Beacon, something experts say could disqualify T1 from the tax credits it is seeking. T1 was formed after Changzhou, China-based Trina Solar, one of the five largest solar panel manufacturers in the world, sold its newly constructed Texas solar panel factory to the firm in December 2024. Trina had built the plant anticipating that doing so would make it eligible to receive U.S. tax credits designed to encourage more green energy production, but sold it amid heightened bipartisan scrutiny of Chinese companies taking advantage of such tax credits. Last week, the Pentagon placed Trina on its list of companies affiliated with the Chinese military. In addition, the company’s founder and CEO, Gao Jifan, serves as a deputy to the 14th National People’s Congress, which is China’s national legislature and has been described as the country’s “highest organ of state power.” Under President Donald Trump’s 2025 One Big Beautiful Bill Act, projects that are owned or controlled by Chinese companies are denied eligibility for the tax credits in question. The Trump Treasury Department is soon expected to finalize rules for how it will enforce those restrictions, something that could be the difference between a company receiving hundreds of millions of dollars in tax benefits or receiving nothing. T1 sold its first batch of credits for $160 million late last year (its gross profit in 2025 was $55.6 million, for comparison). While T1 has sought to distance itself from Trina and has repeatedly said it is building a domestic supply chain as the Trump administration develops those rules, Trina remains the company’s second-largest shareholder. According to financial disclosures filed late last month, Trina owns 30.7 million shares in T1, equivalent to an 11 percent stake in the company and worth hundreds of millions of dollars. That makes Trina a principal shareholder in T1, a formal classification that means it has significant influence over the company. T1 separately reported in its annual filing with the SEC in late March that it maintains a business relationship with Trina: The Chinese solar behemoth remains under contract with T1 to provide advisory, manufacturing, training, and logistics support at T1’s Texas plant. Trina also handles the marketing and sales for solar panels made at the plant. In exchange for its services, T1 pays Trina a share of its earnings and a commission on its sales. Those contracts don’t expire until late 2029. In addition, T1 reported that Trina was by far its largest customer in 2025, selling it a total of $632.2 million worth of solar panels that year, according to its SEC filing. At the same time, T1 manufactured those solar panels using Trina’s components and services—according to Trina’s own disclosures, in 2025, it sold T1 $95.5 million in goods and $45.8 million in labor. During the first three months of 2026, T1 reported sales of $177.4 million to Trina and reported purchases of $119 million from Trina while paying the Chinese company $8.5 million in commissions and royalty fees, according to T1’s latest quarterly filing submitted in May. The three figures each represent significant year-over-year increases. T1’s sales to Trina have been 99.9 percent of its total net sales in 2026 so far. The Free Beaconreported that T1 reached an agreement with Trina in late 2025 to license Trina’s solar technology not from Trina directly, but from a company in Singapore. T1 made the deal to distance itself from Trina while ensuring it could use its technology. Company spokesman Russell Gold said at the time that Trina “has no control over T1 Energy, period.” And T1 announced this month that it had purchased the battery storage company Kore Power. The Free Beaconreported in February 2024 that the company is co-owned by Chinese battery company DFD New Energy, which is run by a Chinese Communist Party official. In response, KORE Power said that “reducing the equity stake of Chinese shareholders has been a priority of KORE.” T1 declined to comment. T1’s continued business ties to Trina appear to undercut the American-made image it has presented and could threaten its effort to retain eligibility for green energy production tax credits. According to advocates for the American solar energy sector, it presents an important test case for the Trump Treasury Department as it decides how aggressively it will enforce the restrictions laid out by the One Big Beautiful Bill Act. “T1 is the one that’s just been out there so much that if we don’t do something there to signal that there’s going to be enforcement and that we’re going to be looking at these things very closely, I think that it’s going to happen over and over and over,” Thomas Beline, a partner with the trade law firm Cassidy Levy Kent with experience representing U.S. solar companies in China-related litigation, told the Free Beacon, adding that the T1 case is the “tip of the spear.” Nathan Picarsic, the cofounder of the Washington, D.C., supply chain research firm Horizon Advisory, argued that the Treasury Department should implement a multi-pronged test that accounts for various ways Chinese companies can exert control over an American company. Doing so would ensure that companies that appear American, but are effectively controlled by Chinese entities, do not receive U.S. tax benefits.
“It looks like T1 is playing this game as smartly as they can, but there’s still a lot of uncertainty,” he said in an interview. “The risk of dependence and the supply chain risk isn’t as simple as just equity ownership,” Picarsic continued. “The ties that can come from supply dependency or from depending overly on a few different customers induce some of the same risks. That places this challenge on the Treasury Department and IRS to be thoughtful about the complexity of the supply chains and the way that Chinese state-backed actors are looking to sow dependence.” Trina, meanwhile, is itself closely linked to the Chinese government. In addition to its ties to the Chinese military and Chinese Communist Party, Trina has also received substantial subsidies from the Chinese government while evading U.S. tariffs. China’s five-year plans, which serve as a blueprint for its economic and industrial priorities, have emphasized the importance of growing the nation’s solar industry for two decades. As such, China continues to dominate the global solar supply chain, according to the International Energy Agency. “China seeks to dominate the solar industry as a matter of national strategy, and they even want America to pay for Chinese dominance with U.S. tax credits,” said Michael Lucci, the founder, chairman, and CEO of the China watchdog group State Armor. “Federal authorities should closely scrutinize any American companies that are deeply tied to the CCP’s solar national champions, and deny them tax credits if the ultimate beneficiary is a CCP-controlled company.” Published under: CCP , China , Chinese Communist Party , Green Energy , Solar Energy , Texas , Trump Administration 2026 All Rights Reserved Subscribe to the Morning Beacon, where Washington Free Beacon editor in chief Eliana Johnson breaks down the news the way the mainstream media won’t—right in your inbox, every day. By subscribing you agree to Substack’s Terms of Use, our Privacy Policy and our Information collection notice
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By Aman Malik ACEN Corp, the listed renewable energy arm of the Philippines' Ayala Group, has agreed to sell up to a 49% stake in Tejorupa solar-energy project in Rajasthan to Diamond India Renewables One B.V., a Netherlands-based affiliate of Japan's Mitsubishi Corporation, as the company looks to recycle capital from existing assets to fund fresh growth. Two ACEN subsidiaries have signed agreements with Diamond India Renewables paving way for its entry into the special purpose vehicle that is developing the 250 MW solar-power project, according to a filing made by ACEN at the Metro Manila-based stock exchange this week. The deal will be completed in stages. Diamond India Renewables will first acquire an initial 10% voting interest in the project company, with subsequent tranches taking its total stake up to 49%, subject to customary closing conditions and regulatory approvals. ACEN did not disclose the financial terms of the transaction. Rajasthan is one of India's most active markets for utility-scale solar development, drawing sustained investor interest because of the strong resource potential and supportive state policy. The stake sale comes a few months after ACEN moved to take full control of its India business. The company had built its India presence through a joint venture with US-based UPC Renewables, under which the two partners held equal stakes in the platform housing their Indian projects. In February, an ACEN subsidiary bought out UPC India's remaining 50% voting interest in the venture, giving ACEN sole ownership of a portfolio comprising more than 1,000 MW of renewable energy projects under construction and in development across Rajasthan and Karnataka. That buyout also brought into ACEN's fold the three operating solar assets the partners had built together in India. India ranks among ACEN's largest international markets. As of the end of last year, the country accounted for roughly a quarter of the company's net attributable capacity outside the Philippines. ACEN currently operates three solar projects in India with a combined capacity of more than 1,300 MW, in addition to assets under construction and in the pipeline. The latest transaction underscores a broader trend in India's renewable energy sector, where developers are increasingly looking to bring in strategic investors at the project level to free up capital for new development, while retaining a foothold in a market that continues to attract significant international investment in utility-scale solar and wind. ACEN's group chief investments officer, who also serves as president and chief executive of ACEN International, has said previously that India is a core market for the company's overseas expansion, and that the deal reflects long-term confidence in the country's renewable energy sector. Beyond India and the Philippines, ACEN holds renewable energy assets in Australia, Vietnam, Indonesia and Laos, as well as the United States. Across these markets, the company's attributable renewable energy capacity stands at roughly 7 GW, spanning operating, under-construction and committed projects. Share article on Follow VCCircle on Google News for the latest updates on Business and Startup News Insights Focus is a marketing initiative for posts. No VCCircle / TechCircle journalist was involved in the creation of this content. Copyright @ 2026 VCCircle.com. Property of Mosaic Media Ventures Pvt. Ltd., a part of Mosaic Digital, a 100% subsidiary of HT Media Limited.
The UK government has launched a public consultation to enable the use and sale of plug-in solar systems, a technology that would allow consumers to generate electricity using small photovoltaic panels connected directly to a standard household socket. The consultation, launched by the Department for Energy Security and Net Zero (DESNZ), proposes amending existing regulations to allow these systems to be connected without the need for a conventional rooftop solar installation, provided they meet a set of safety and performance requirements. The initiative aims to expand access to self-generation for groups that currently face greater barriers to installing traditional solar systems, including renters, apartment residents and households without suitable roof space for photovoltaic installations. The proposal has received backing from some of the UK’s largest retailers. Amazon, Currys, B&Q, Lidl, Asda, Wickes and Screwfix took part in a government roundtable to discuss the potential of the technology and its future commercialization in the British market. According to the government, plug-in solar systems could provide a more affordable way for households to reduce their reliance on grid electricity and lower part of their energy consumption costs. The interim technical specification proposed by the government establishes a maximum output of 800 VA and a maximum current of 3.5 amps. The systems must include a grid-connected microinverter, use standard UK household plugs and comply with a range of electrical safety, fire protection, electromagnetic compatibility and automatic disconnection requirements in the event of grid disturbances. The proposal initially limits installations to one system per household and excludes products with integrated battery storage. According to the government’s analysis, plug-in solar kits currently available in Europe cost between £400 and £600 for an 800 W system. This is significantly lower than the average cost of a conventional residential solar installation in the UK, which stands at around £1,595 per kilowatt installed. The government believes that this lower entry cost could help expand access to distributed solar generation for households that are unable to afford a full rooftop solar installation. The consultation is supported by a technical study commissioned by the UK government to assess how these systems perform within domestic electrical installations. The report concluded that plug-in solar systems can operate safely in UK homes without requiring modifications to existing wiring, consumer units or protection devices, provided they operate within the defined technical limits and comply with the proposed certification requirements. The assessment examined thermal performance, overload protection, response to grid faults, electromagnetic compatibility and interactions with typical household electrical systems. Solar Energy UK welcomed the regulatory progress and said the consultation will help establish a dedicated regulatory framework for a technology that previously lacked a clear legal pathway in the British market. The association noted that the development of technical standards and safety requirements will provide greater certainty for manufacturers, retailers and consumers, while also supporting the integration of this new self-consumption category into the country’s electricity system. The initiative forms part of the UK’s broader strategy to accelerate renewable energy deployment and achieve its clean power targets by 2030. According to government figures, 269,000 solar installations were completed across the country in 2025, setting a new annual record. Around 255,000 of those were rooftop installations, accounting for approximately 95% of all new solar capacity deployed during the year. The consultation will remain open until 30 June 2026 and will help shape the final regulatory framework that could allow plug-in solar products to enter the UK market in the coming months. Sé el primero en comentar…
NTPC Renewable Energy Ltd (NTPC REL) has launched a tender inviting bids for the engineering, procurement and construction (EPC) packages for 1,090 MW/4,360 MWh of interstate transmission system (ISTS)-connected battery energy storage systems (BESS) across its three solar project sites in Rajasthan. The tenders cover a 240 MW/960 MWh BESS at the Devikot solar plant, a 550 MW/2,200 MWh BESS at the Shimboo Ka Burj solar plant, and a 300 MW/1,200 MWh BESS at the Nokhra solar plant. All three projects are based on four-hour storage duration. The selected EPC contractor will be responsible for design, engineering, supply, installation, testing, and commissioning of the grid-connected battery storage system on a turnkey basis. The scope of work also includes comprehensive operation and maintenance (O&M), including performance insurance, warranty coverage, and an annual maintenance contract under a service-level agreement for a period of 15 years. According to the tender specifications, the BESS must have a design life of 25 years from the date of commissioning, with capacity degradation as per the bidder’s proposal considering daily single-cycle operation. Batteries must be rated for minimum 10,000 cycles of operation. The bidder must guarantee minimum 98% of dispatchable capacity at POI across all 15 years starting with 100% of rated dispatchable capacity for the first year. Comments Please login to comment The June issue of pv magazine Global is out now! Available in print and digital – get your copy today! Thursday, July 9, 2026 11:00 am – 12:30 pm CEST, Berlin, Paris, Madrid Thursday, June 18, 2026 2:00 pm – 3:00 pm CEST, Berlin, Paris, Madrid Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects. April 01 – August 31, 2026 pv magazine Insight will be held on October 30, at The Battery Show India Expo 2025 and moderated by pv magazine’s Uma Gupta and Mark Hutchins.
Xinyi Solar’s ultra-clear photovoltaic glass may not sit on your roof itself, but it shapes how efficient and affordable modern solar modules become. The industrial sheets target panel makers that need consistent quality, durability, and tight cost control at scale. Reviewed: ad hoc news Software & Services desk. Edited and checked on 2026-06-18, 15:49. Details in the imprint. With its ultra-clear photovoltaic glass for solar modules, Xinyi Solar supplies the silent workhorse that decides how much sunlight really reaches the cells. The glass looks almost ordinary, yet its iron-poor clarity and toughened surface aim directly at panel makers’ yield and warranty costs. Xinyi Solar links its glass business with its Hong Kong listing, giving investors direct exposure to demand from global module makers. At first glance it is just a sheet of glass, but Xinyi Solar’s ultra-clear photovoltaic glass uses low-iron formulations to improve light transmittance compared with standard float glass. Panel makers squeeze extra module efficiency out of every cell with this higher clarity. The company emphasizes controlled thickness, flatness, and surface quality so that fully automated module lines can laminate at high speed without frequent breakage or optical defects. This quiet reliability matters more than any marketing slogan on a finished rooftop panel. Once installed, the glass must survive decades of hail, sand, and sudden temperature swings on open roofs and solar farms. Xinyi Solar tempers and chemically strengthens its glass, targeting high mechanical load ratings and resistance to micro-cracks during handling. Anti-reflective surface treatments further reduce light lost at the air-glass interface, especially under low-angle morning and evening sun. That small gain, multiplied across millions of modules, adds up to meaningful extra kilowatt-hours for project owners over a 25-year lifetime. Xinyi Solar produces its photovoltaic glass in large integrated bases in mainland China to keep unit costs down for module manufacturers at home and abroad. Its customer list spans Chinese heavyweights and export-focused panel assemblers shipping to Europe, India, and emerging markets. To keep up with demand for high-performance solar modules, the company is investing in additional ultra-clear solar glass production lines in Ordos, Inner Mongolia, each with a substantial daily melting capacity according to recent company disclosures. This expansion underlines how glass supply has become a strategic bottleneck in the solar chain. Module makers ultimately care about three things when choosing glass: power output, breakage rate, and cost over the full run. With ultra-clear formulations and stable coating quality, Xinyi Solar tries to squeeze a few extra watts from each panel while keeping defect rates low. For installers and project developers, the glass choice shows up in real life as modules that degrade more slowly and keep their rated output closer to the original data sheet. Fewer cracked modules during transport and mounting also helps large solar parks stay on schedule and on budget. There is no retail price tag here, because Xinyi Solar’s photovoltaic glass is sold in bulk contracts directly to module manufacturers, often indexed to raw glass and energy costs. Negotiations typically weigh planned production volumes against guaranteed delivery slots. European rooftop owners will never order this glass by name. Instead they encounter it indirectly inside panels from their preferred brands, which in turn depend on Xinyi Solar to keep quality and deliveries stable even when energy and logistics markets turn volatile. Xinyi Solar ties this glass business into a broader footprint in solar materials and power assets, positioning itself as a key supplier in China’s photovoltaic ecosystem. Shares of Xinyi Solar Holdings Ltd (HK0968003713) traded on the Hong Kong Stock Exchange at 3.43 HKD on 2026-06-17, based on recent quote data. This article was AI-assisted and editorially reviewed. Product information without guarantee; prices and availability may change at short notice. No investment advice, no buy or sell recommendation. Stock-market transactions involve risks up to total loss.
By: Luis Reyes Published: Jun 18, at 9:00am ET Solar farms go where the land is cheap and the sun is reliable. Most of the time that means a desert, a stretch of scrubland nobody is farming, or the roof of a distribution center. China has spent the last decade pushing that idea about as far as it will go on dry land, from a 250-mile “great wall” of panels strung across the Kubuqi desert to a Tibetan-plateau array so productive that the operator had to bring in thousands of sheep to keep the grass from shading the modules. The newest one skips the land question entirely. It sits about five miles off the coast of Dongying, in Shandong province, bolted to the seabed on nearly 3,000 steel platforms, with fish farming going on in the water underneath. That project is called HG14, and as of late December 2025 it is fully wired into the grid. Built by Guohua Energy Investment, a subsidiary of state-owned China Energy Investment Corporation (CHN Energy), it is a 1-gigawatt photovoltaic plant that the company bills as the world’s first gigawatt-scale offshore solar farm, and the largest sitting in open sea anywhere. The “offshore” part is doing real work, because almost every big floating solar project you have read about lives on a calm reservoir or an inland lake. This one is out in the actual ocean, in a bay that ices over in winter. Worth getting the engineering straight first, because “floating solar farm” is the label that keeps getting stuck on HG14 and it is not quite right. The plant does not float. It is a fixed-pile system: steel piles are driven into the seabed, and the platforms holding the panels sit rigidly on top of them. That approach works here because the water is shockingly shallow, between roughly 3 and 13 feet (one to four meters) deep across the entire 1,223-hectare site, which works out to about 4.7 square miles, or close to a fifth of Manhattan. At that depth you can anchor straight to the bottom instead of building expensive floating pontoons, and you end up with a far sturdier structure. Sturdiness is the whole game out there, because the waters off Kenli district turn genuinely hostile in winter. Air temperatures drop below 14°F (-10°C), Siberian winds push saline spray that can freeze on contact, and the shallow bay forms sheets of sea ice. CHN Energy says the fixed-pile design was engineered specifically to take waves, tides, strong winds and seasonal ice without buckling. There are 2,934 of those platforms by the developer’s count, each one about 197 by 115 feet (60 by 35 meters), held down by a combined 11,736 steel piles. To put them in fast enough, the construction crews used a setup that drives four piles into the seabed at once with automated leveling, which is the kind of unglamorous detail that decides whether a project like this finishes this decade or next. Building solar at sea sounds like an answer to a problem nobody has, given how much empty land is lying around. But eastern coastal China is not empty. It is where the people and the factories are, and flat, cheap, sun-soaked land near those load centers is genuinely scarce. Parking a gigawatt of panels just offshore puts the electricity right next to where it gets consumed, without bulldozing farmland or picking a fight over a desert. The catch is that this exact approach only works in a narrow set of places. Fixed-pile offshore solar needs a shallow coastal shelf with a stable seabed that can hold the piles and ride out the local wave climate, and most coastlines simply do not offer that. So while the topline makes HG14 sound like a blueprint the rest of the world can photocopy, the conditions behind it (a broad, shallow, ice-prone bay sitting right next to a major demand center) are fairly specific. It is less a universal template than a very good use of one unusual stretch of sea. The record here is not just about size. HG14 is the first time China has paired a 66-kilovolt offshore cable with an onshore cable to move solar power that far at high capacity, with the current stepped up to 220 kilovolts once it reaches land. It is also, according to pv magazine, the first offshore solar facility approved under China’s national three-dimensional sea-use rights framework, which is the bureaucratic machinery for letting more than one industry legally share the same patch of water. Pairing the panels with on-site storage and that transmission setup lifts the plant’s effective capacity by around 20% and trims unit costs by roughly 15%, per CHN Energy’s figures. “The project provides valuable experience for future offshore solar farm construction,” Zhang Bo, deputy manager of the Kenli project at Guohua Energy Investment, told state broadcaster CGTN, as Electrek relayed. Which is corporate-speak for “we are going to build more of these.” No spam. Unsubscribe anytime. Privacy policy (opens in new window) The detail that tends to stop people is the second business running in the same water. HG14 uses what CHN Energy calls an integrated fishing-and-PV model: power generation up on the platforms, aquaculture in the sea below. The company expects the fish farming alone to bring in more than 27 million yuan a year, roughly $3.8 million, on top of whatever the electricity earns. The panels throw shade and the structure offers shelter, which in theory makes the water beneath friendlier to farmed fish than open sea. On the power side, the developer’s own numbers are the ones to weigh, since this is a state operator reporting on its own project. CHN Energy says HG14 will generate around 1.78 terawatt-hours a year at full output, enough by its math to cover about 2.67 million urban residents and roughly 60% of Kenli district’s total electricity demand. It puts the annual savings at 503,800 tons of coal and 1.34 million tons of CO2 avoided. A 100-megawatt, 200-megawatt-hour battery sits alongside the array to soak up midday generation and push it back onto the grid at full power for about two hours when it is needed most. It is tempting to read a gigawatt of offshore panels as China running away with the energy transition, and the national numbers do look like that from a distance. By the end of 2025 the country’s installed solar capacity reached about 1,200 gigawatts, up roughly 35% in a single year, according to its National Energy Administration. Wind and solar combined first passed China’s thermal (mostly coal) capacity back in early 2025, and Carbon Brief reports that the China Electricity Council expects solar capacity alone to overtake coal for the first time during 2026. Capacity is not the same as electricity, though, and that is where the tidy version falls apart. Solar plants in China run at an average capacity factor of around 14%, against roughly 50% for coal, so a coal station still puts out several times more actual power per gigawatt installed. China also kept building coal hard last year: developers put forward about 161 gigawatts of new coal-fired capacity in 2025, per the Centre for Research on Energy and Clean Air and Global Energy Monitor, even as coal-fired generation itself slipped around 2%, its first drop in six years. Coal is not being switched off. It is being nudged toward backup and grid-balancing while the renewables get built out around it. So HG14 is a real, working gigawatt sitting in the open ocean, which is a new thing and a hard one to pull off in a bay that freezes solid every winter. It is also a single project, in shallow water that happens to suit it, owned by a utility that controls exactly how the numbers get reported. Both of those are true at once. The real test is the next one: whether a fixed-pile plant like this turns up somewhere the water is deeper and the permitting is messier, or whether five miles out to sea stays a Shandong specialty. Image credits: cscec.com Did we nail it or blow it? Luis Reyes · Jun 10, 2026 Olivia Richman · Jun 11, 2026 Dave McQuilling · May 30, 2026 Olivia Richman · May 30, 2026 Dave McQuilling · May 23, 2026 Luis Reyes · May 25, 2026 Luis Reyes · Jun 18, 2026 Luis Reyes · Jun 18, 2026 Luis Reyes · Jun 18, 2026 Olivia Richman · Jun 17, 2026 Luis Reyes · Jun 17, 2026 Autonotion is the English-language automotive editorial by Autonocion.com — car news, reviews, and industry analysis for American readers. Other links Company Subscribe Get the latest car news in your inbox: By submitting your email you allow autonocion.com to send you news or promotions. More info
Norwegian independent power producer (IPP) Scatec has reached financial close for the 120MW Sidi Bouzid II solar PV project in Tunisia. The project is being developed in partnership with Aeolus SAS, part of the Toyota Tsusho Group, with Scatec and Aeolus each holding a 50% ownership stake. The plant is under construction and is expected to enter commercial operation in the second half of 2027. Get Premium Subscription Total capital expenditure for the project is estimated at €96 million (US$110 million) and will be financed through a combination of non-recourse debt and equity, with leverage of approximately 70%. “Sidi Bouzid II is our third project starting construction in Tunisia and reinforces our partnership with Aeolus and our position in Tunisia, with strong fundamentals for renewables and strong growth potential. The project demonstrates our ability to scale our business through repeatable tender-based opportunities, backed by a strong partnership with Aeolus, and a capital-light execution model,” says Terje Pilskog, CEO of Scatec. The project has secured financing from the European Bank for Reconstruction and Development (EBRD) and the European Investment Bank (EIB), while additional support comes from grant funding provided through the EU Neighbourhood Investment Platform (NIP) and guarantees from the European Fund for Sustainable Development Plus (EFSD+). Scatec will deliver engineering, procurement and construction (EPC), asset management and operations and maintenance (O&M) services for the project. The company’s EPC contract scope represents approximately 75% of the project’s total capex. The project is backed by a 25-year power purchase agreement (PPA) with Tunisian state utility Société Tunisienne de l’Electricité et du Gaz (STEG). Tunisia currently relies heavily on natural gas for electricity generation, with 95% of its power production sourced from the fuel and more than 60% of gas supplies imported. The country has set a target of sourcing 35% of its electricity generation from renewable energy by 2030 as it seeks to reduce generation costs and improve energy independence. The Sidi Bouzid I solar plant, with a capacity of 60MW, reached commercial operation in March 2026.
Perovskite solar module manufacturer Oxford PV announced it achieved a power conversion efficiency of 25.6% for a perovskite-silicon tandem solar module relying on a shingled architecture developed by Germany’s Fraunhofer Institute for Solar Energy Systems (Fraunhofer ISE). “For the first time, the two organizations have successfully combined Oxford PV’s perovskite-silicon tandem solar cells with Fraunhofer ISE’s Matrix Shingle module technology,” Ed Crossland, CTO of Oxford PV, told pv magazine. “Beyond the efficiency gains, the combination also reduces resistive losses, removes the need for copper interconnects, and improves resilience under partial shading – all key considerations as the industry looks to reduce costs while increasing energy yield.” “The module presented is a prototype, but it is built using standard production cells and in a way that is fully compatible with mass production. Our current tandem modules are already delivering efficiencies of 25% with 10-year lifetime today, and this result builds directly on that. We continue to make progress along our roadmap, with a 26% product planned for release this year and a path to 27% with extended lifetimes by 2027,” Crossland added. The Matrix Shingle approach improves conventional solar module interconnection by replacing traditional busbar-and-ribbon architectures with a dense, overlapping cell layout. In this method, photovoltaic cells are precision-cut into narrow strips and reconfigured into a shingled pattern, similar to roof tiles. Adjacent strips overlap slightly and are bonded using electrically conductive adhesive (ECA), which provides both mechanical adhesion and electrical interconnection between neighboring cell segments. By eliminating soldered interconnect ribbons and busbars, the architecture removes inactive spacing that would otherwise block incoming light. As a result, optical shading losses are significantly reduced and a larger fraction of the module surface becomes active photovoltaic area, improving packing density. The reduction in metallization shading also enhances current collection efficiency, as more of the cell surface is exposed to sunlight. In addition, the shingle configuration shortens current pathways and distributes current more uniformly across the module, which can reduce resistive losses and localized heating. The use of ECA instead of high-temperature soldering also reduces thermal stress during assembly, helping to preserve cell integrity and potentially improve long-term reliability. Overall, the Matrix shingle approach increases module power density by combining higher active-area utilization with improved electrical and optical performance. “We are delighted to be able to combine two high-tech approaches from Europe in this PV module,” said Stefan Glunz, head of photovoltaics at Fraunhofer ISE. “To achieve this, we have cut the solar cells from Oxford PV into shingles, arranged them in a matrix structure, electrically connected them using conductive adhesive, and then encapsulated them.” Two tandem glass-glass modules were built with this configuration and edge sealing to protect the moisture-sensitive solar cells: a 491 W rooftop module with an area of 1.92 m², and a 546 W bifacial module with an area of 2.13 m². “Both achieved an efficiency of 25.6% across the entire module area,” Oxford PV’s spokesperson said. “Our tandem technology and the shingle interconnection work well together technologically,” said Ed Crossland, chief technology officer at Oxford PV. “Due to the lower current densities of the perovskite–silicon solar cells, they can be cut into wider strips, which increases productivity. Tandem solar cells achieve significantly higher voltages and efficiencies than conventional cells, while the current is lower due to distribution across two sub-cells. This lower current density is beneficial, as it helps reduce resistive losses within the PV module. At the same time, the adhesive interconnection of the Matrix shingle technology is a low-temperature process and requires no copper connectors.” Oxford PV unveiled its first perovskite-silicon tandem solar module with 26.9% efficiency in June 2024. A few months later, the company announced the commercial launch of perovksite-silicon tandem modules in the United States. It began working on its perovskite tandem solar modules in 2014 and claims to have a “clear roadmap” to bring the technology to over 30% efficiency. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: [email protected]. Comments Please login to comment The June issue of pv magazine Global is out now! Available in print and digital – get your copy today! Thursday, July 9, 2026 11:00 am – 12:30 pm CEST, Berlin, Paris, Madrid Thursday, June 18, 2026 2:00 pm – 3:00 pm CEST, Berlin, Paris, Madrid Be part of the high-level European conference on solar and energy storage, exploring bankable BESS projects, warranties, and energy management for residential and C&I sectors Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects. April 01 – August 31, 2026 A two-day conference in Austin, Texas, bringing together leaders in US solar manufacturing, equipment specification, and factory execution. Saudi Arabia is accelerating its clean energy transition—join the SunRise Arabia Clean Energy Conference 2026 in Riyadh to explore how solar PV and energy storage are powering its digital economy. Showcase your brand across all our platforms: from 13 websites in 7 languages to our magazines, daily newsletters, industry events and more. Reach your audience the right way! We are participating in Intersolar 2026 again this year! Visit us at our Booth Hall 2 A2.250 to discuss the latest trends within the photovoltaic industry with the pv magazine team. June 23-25, 2026 | MUNICH, GERMANY
Our website uses cookies to enhance your browsing experience. By using our website you agree to the use of cookies as per our privacy policy Explore why rooftop solar for MSMEs in India remains largely untapped, and what is needed to make solar adoption easier and accessible for smaller businesses. Jun 18, 2026 Sections The MSME sector contributes around 30% to India’s GDP, over 35% of manufacturing output, and nearly 45% of exports (Ministry of Micro, Small & Medium Enterprises), while supporting livelihoods across the country. Yet despite its economic importance, MSME solar adoption in India remains limited even as solar deployment accelerates elsewhere. This raises an important question. If solar has already scaled across India, why has that momentum not reached smaller businesses at the same pace? The answer may lie not in whether solar works, but in how easily it fits into the realities of MSME operations. Why MSMEs think differently about energy The gap is structural, not just awareness-led. Large corporates can evaluate solar through long-term savings, dedicated teams, and easier access to capital. MSMEs operate in a different reality, where decisions are owner-led, cash-flow driven, and risk-sensitive. Even when SME solar solutions in India offer attractive payback, upfront costs, trust gaps and operational concerns often delay solar adoption despite the sector’s clear need and potential. High energy dependence, low optimization Despite their economic weight, many MSMEs operate in energy-intensive sectors such as textiles, metals and ceramics, together accounting for a sizeable share of India’s industrial energy use. Unlike large industries, they often depend on grid supply at higher tariffs and with limited flexibility. This makes solar for small businesses in India financially compelling, but energy is still treated as an operating expense, not a strategic investment, leaving rooftop solar for MSMEs underused despite India’s rapid solar growth. MSMEs are naturally aligned with how solar power is generated and consumed. Most units operate during daytime hours, allowing rooftop solar for MSMEs to directly offset grid electricity use without requiring storage or load shifting. This improves utilization and makes decentralized solar operationally relevant for the sector. MSMEs also account for a significant share of industrial electricity demand, making them an important segment for India’s clean energy transition. Electricity is a major operating cost for MSMEs – This makes even small reductions in electricity costs financially meaningful. For many businesses, solar becomes less of a sustainability decision and more of a cost optimization strategy. The economics of solar remain compelling – This creates potential savings of ₹2–₹4 per unit, making SME solar solutions in India an attractive option for businesses operating on tight margins. Over time, these savings compound into meaningful cost reductions and improved competitiveness. Despite strong economics and operational alignment, adoption remains low. MSMEs consume roughly half of industrial electricity while offering significant rooftop potential, yet deployment remains disproportionately low. This highlights the gap between the business case for rooftop solar for MSMEs and actual implementation. Limited access to financing For many businesses, the biggest challenge is not intent but capital. As a result, viable projects frequently stall at the financing stage despite offering strong long-term returns. Awareness and information gaps Many businesses understand the concept of solar but lack clarity on: Without trusted advisory support, solar for small businesses in India often remains a consideration rather than a decision. (Source: Climate Investment Funds, Deloitte) Policy and regulatory complexity Even when financing is available, businesses may face challenges related to – For smaller enterprises with limited internal resources, these complexities can delay adoption. Operational constraints on the ground Many MSMEs operate under practical limitations – These challenges can make deployment difficult despite strong financial fundamentals. Perceived risk vs immediate business priorities At its core, the hesitation is behavioral as much as structural. MSMEs prioritize survival and liquidity – This is where SME solar solutions in India often fail to connect. The value proposition is long-term, while MSME decision-making is immediate. For MSMEs, the impact of solar begins with the balance sheet. For businesses operating on thin margins, even modest savings can create a meaningful advantage. This is where solar for small businesses in India moves beyond efficiency and becomes a competitive lever. The environmental benefits are equally significant. As supply chains increasingly prioritize sustainability, SME solar solutions in India can also strengthen long-term business relevance. India is targeting 500 GW of non-fossil fuel capacity by 2030, with solar playing a central role. This makes MSME solar adoption in India important not only for businesses, but for the country’s energy transition. The greatest impact may emerge at the cluster level. Industrial hubs such as textile parks, foundries, and food-processing zones can benefit through – India added more than 5 GW of rooftop solar capacity in FY2025, highlighting growing momentum in decentralized energy adoption. If MSMEs participate at scale, they could become one of the strongest drivers of India’s clean energy transition. (Source: JMK Research, Annual India Solar Report Card FY2025). New financing models, digital platforms, and policy support are making solar adoption more accessible, helping convert strong solar economics into practical business outcomes for MSMEs. OPEX and RESCO models reducing upfront burden Demand aggregation and cluster-based deployment Digital platforms simplifying adoption Government schemes and subsidy evolution
One of the biggest shifts in MSME solar adoption in India has been the emergence of OPEX and RESCO models. Individually, MSMEs may be small, but collectively they represent a significant market opportunity. These models directly address one of the biggest barriers to MSME solar in India: fragmented demand. Digital tools are helping simplify the solar adoption journey by enabling – By reducing process complexity, these platforms make solar for small businesses in India easier to evaluate and implement. Policy support continues to improve project viability through: While implementation still varies across states, continued policy evolution is helping create a more supportive environment for SME solar solutions in India. As these solutions scale, the gap between solar potential and actual adoption is expected to narrow significantly. Helping MSMEs turn solar economics into business advantage Tata Power's strength lies in its ability to operate across the entire solar value chain, from manufacturing and financing support to installation and maintenance. Today, Tata Power has built one of India's largest rooftop solar portfolios – This positions Tata Power as a provider that understands the operational realities of businesses across industries and scales. Tata Power has focused on addressing one of the biggest barriers to MSME solar adoption in India: financing. As Dr. Praveer Sinha, CEO & MD, Tata Power, noted – "MSMEs are the backbone of India's economy. They operate across industrial segments and are major consumers of electricity. Our strategic collaboration with SIDBI will facilitate the ease of opting for renewable energy in the MSME sector and power its quest to become more efficient and globally competitive." For many MSMEs, complexity can be a bigger challenge than technology itself. Tata Power helps reduce that complexity through – Trust and execution capability are often decisive factors for businesses evaluating rooftop solar for MSMEs, and end-to-end delivery helps reduce both risk and effort. Solar should be evaluated on lifetime value rather than installation cost alone. With rooftop solar tariffs ranging from ₹3.8–₹6.5 per kWh compared to ₹5.6–₹9.9 per kWh for grid electricity, the focus should be on long-term savings, payback periods, and energy cost reduction over 20–25 years. Choosing the right ownership model is critical. The right approach depends on how the business balances cash flow, risk, and investment priorities. Before installation, MSMEs should assess – Since MSMEs account for a significant share of industrial energy demand, correct load matching is essential to maximize value from rooftop solar for MSMEs. Execution quality ultimately determines project success. Businesses should prioritize partners with – The right partner not only installs a system but helps ensure that projected savings become measurable for business outcomes. If you’re looking to understand the solar journey end-to-end before choosing the right partner, this guide to solar energy breaks it down step by step.
India’s solar journey is entering its most meaningful phase yet – not just scaling capacity but expanding impact. MSMEs sit at the heart of this shift, where every rooftop has the potential to become a growth engine. The economics already work. The solutions are getting simpler. And with trusted players like Tata Power enabling access, the path is clearer than ever. What was once seen as a long-term investment is quickly becoming a smart business move. And as that shift takes hold, MSMEs will no longer sit on the edge of India’s energy transition; they will be one of the forces driving it forward.
Yes, MSMEs need DISCOM approval. Every rooftop solar for MSMEs project must get approval from the local DISCOM before installation. The process is now largely online through national or state portals, which has made things smoother than before. For MSME solar India projects, delays usually happen at this stage. Once approval is cleared, installation itself is relatively quick and straightforward with the right partner
For most MSMEs, the challenge is not “why solar” but “how to actually do it.” This is where players like Tata Power become relevant. By offering end-to-end support, from assessment to maintenance, they reduce the number of decisions a business needs to make. That shift turns solar from a complicated project into a manageable, almost plug-and-play business upgrade
If your system produces more electricity than you consume, the excess can be exported back to the grid through net metering, depending on state policies. This helps offset future electricity bills and improves overall savings. For MSMEs in India, this feature makes solar not just a cost-saving tool but also a way to optimize energy usage more efficiently.
System sizing is important for MSMEs when it comes to monetary returns. Many DISCOMs link system size to sanctioned load and consumption to prevent oversizing. For rooftop solar for MSMEs, oversizing can reduce efficiency and delay payback. The best-performing systems are not the biggest ones. They are the ones that match actual usage and maximize self-consumption
MSMEs typically operate during daytime hours, aligning closely with solar generation cycles. For solar for small businesses in India, this improves self-consumption and reduces dependence on storage. Combined with high electricity cost sensitivity, MSMEs are structurally one of the best-fit segments for solar, even though adoption has not yet caught up with this advantage
By: Luis Reyes Published: Jun 18, at 11:42am ET Everyone knows what solar panels do. You bolt enough of them to a roof or a field, the sun hits them, and you get electricity instead of a power bill. That part is settled. But a team of German climate scientists working in the Gulf has spent the last few years chasing a stranger possibility: that if you build a solar farm big enough, in exactly the right spot, the thing might start making its own rain. Not as a metaphor. Actual clouds, actual water falling out of the sky over one of the driest places on Earth. And as of this spring, the idea has officially graduated from “interesting model on a computer” to “we are now hauling laser equipment into the desert to see if it holds up.” The whole thing rides on convection, which is the same boring process that makes a summer thunderstorm. The sun heats the ground, the hot ground heats the air above it, that warm air rises, and if it climbs high enough into cooler altitudes carrying moisture, the water vapor condenses into clouds and eventually falls back down as rain. Cities do an accidental version of this all the time. Asphalt and concrete soak up more heat than grass and dirt, which is why a downtown core runs hotter than the suburbs around it, and that extra heat can nudge rainfall downwind. Dark solar panels do the same trick, just more so. They are built to absorb sunlight rather than bounce it back, so a big enough array becomes an artificial hot patch sitting in the middle of a cool, reflective desert. The bigger the temperature gap between the panels and the sand around them, the harder the air gets shoved upward. Get the updraft strong enough, hand it a supply of moist air, and in theory you have the front end of a rain cloud. No spam. Unsubscribe anytime. Privacy policy (opens in new window) That last ingredient is the catch, and it is also why the United Arab Emirates is the test case rather than, say, the middle of the Sahara. The UAE has a hyper-arid interior but a humid sea breeze rolling in off the Persian Gulf every day. The breeze brings the water. The panels bring the heat. The hope is that the two meet over the array and go up together. The numbers come from a modeling study led by Oliver Branch, a climate scientist at the University of Hohenheim in Germany, published in the journal Earth System Dynamics and covered widely in the science press. Rather than simulate real solar panels, the team modeled an “artificial black surface” cranked up to absorb 95% of incoming sunlight, which is darker than most panels actually are, and ran it in a weather prediction system at five sizes: 10, 20, 30, 40, and 50 square kilometers. The 10-square-kilometer version did nothing. Too small to move the atmosphere. But once the surface hit roughly 20 square kilometers, the model started spitting out measurable rain within a 90-kilometer radius. As Freethink laid out, the paper estimated that a single pair of 20- or 50-kilometer surfaces, firing off about ten rainfall events in a summer, could supply enough water for somewhere between 3,000 and 15,000 people depending on the size. Branch put it about as plainly as a scientist is willing to: “Maybe it’s not science fiction that we can produce this effect.” For context, the UAE currently chases rain the old-fashioned modern way, with cloud seeding, flying roughly 300 missions a year to dump particles into existing clouds and coax water out of them. The problem with seeding is that you need clouds there in the first place, and you need pilots willing to fly into them. A solar farm that brews its own weather on the ground, while also generating gigawatts of electricity, would be a fundamentally different kind of tool. Here is where the story stops being a two-year-old paper and becomes current. In May 2026, pv magazine reported that the concept has moved into a funded, multi-year field project. The money comes from the UAE Research Program for Rain Enhancement Science, which puts $5 million a year into precipitation research, and Branch’s proposal was picked from around 120 international submissions for three years of funding. He’s running it alongside Volker Wulfmeyer, his colleague at Hohenheim, and the two have spent more than a decade studying how deserts move heat and moisture around. The plan is to stop guessing and start measuring. The team is deploying high-resolution LiDAR systems near real solar installations in the UAE, including the Mohammed bin Rashid Al Maktoum Solar Park outside Dubai, to capture three-dimensional profiles of temperature, humidity, and wind all the way up to the altitude where clouds form. That field data then feeds ultra-high-resolution weather simulations run on a pair of supercomputers, Hunter and HoreKa, operated by the University of Stuttgart and the Karlsruhe Institute of Technology. The goal is to nail down the optimal size, placement, and panel design to actually trigger rain instead of just modeling that it might. They are also looking at something genuinely odd: building artificial dunes several hundred meters tall to act as man-made mountains. Real mountains force incoming air to rise and dump its moisture on the windward side, which is why one slope of a range is lush and the other is desert. The idea is to fake that effect with engineered terrain and stack it on top of the heat-island effect from the panels. The Dubai site is a useful yardstick for whether any of this is buildable at the right scale. The Mohammed bin Rashid Al Maktoum Solar Park reached 3,860 megawatts of installed capacity by the end of 2025, and DEWA has revised its 2030 target sharply upward to exceed 7,260 megawatts, well past the original 5,000-megawatt goal. Branch has said elsewhere that some solar farms are already getting close to the footprint his model needs. The world is, almost by accident, building installations in the right size range. Nobody designed them to make rain, but the raw scale is arriving anyway. The Gulf is not the only candidate, either. Branch’s team has pointed to a couple of other coastlines where the same recipe might work, naming Namibia and Mexico’s Baja Peninsula. This is real science from a credible team, not a viral aggregator headline, and it deserves to be taken seriously. It also comes with a stack of caveats big enough that anyone telling you solar panels “make it rain” is getting ahead of the evidence by a wide margin. Start with the obvious one: this is a model graduating into a measurement campaign, not a working rain machine. Nobody has built a solar farm and watched it conjure a storm. The simulation also used a surface darker than commercial panels actually are, which means real-world arrays would need special coatings or dark ground cover between the rows to hit that 95% absorption figure. And the original case studies didn’t run on random summer days. The team picked days with partially unstable weather to give the effect the best possible shot, so the regularity of those conditions in any given location is its own open question. Then there’s the scary version. A separate line of research on covering the Sahara with solar found that doing it at continental scale could disrupt atmospheric teleconnections and shift cloud cover thousands of miles away, with knock-on effects reaching North Africa, southern Europe, the southern Arabian Peninsula, India, North Asia, and even eastern Australia. Local rain in one desert is not the same as quietly rewiring the planet’s weather, and the line between “useful regional tool” and “global side effects” is exactly the kind of thing the new field data is meant to pin down before anyone gets ambitious. The honest framing is that the UAE itself isn’t betting the farm on this either. The country remains committed to its cloud seeding program while it studies the convection idea on the side, which is roughly the posture you’d expect from a government that needs water now and is happy to fund a long shot in parallel. The interesting thread here isn’t really about rain. It’s that we keep discovering that giant solar installations do things their designers never planned for. China’s largest array turned a high-altitude sand desert into enough grassland that operators had to bring in sheep to keep the vegetation from shading the panels. France spent five million euros on a solar road that cracked apart and got torn up after eight years. And Tesla’s own Solar Roof has quietly faded from the product it was hyped to be. Solar at scale is full of surprises, and not all of them are the good kind. What makes the rain project worth watching is that it treats one of those accidents as a feature instead of a footnote. If the field data holds up, a desert nation could end up with a single piece of infrastructure that generates clean power and freshwater at the same time, which would be a genuinely big deal in a part of the world where water is worth more than oil. If it doesn’t hold up, it joins the long list of solar’s weird unintended consequences. Either way, the next few years of LiDAR data out of the Gulf will settle whether the clouds were ever really there, or just hiding in the model. Don’t bite your tongue. Speak up. Luis Reyes · Jun 4, 2026 Luis Reyes · Jun 16, 2026 Olivia Richman · May 28, 2026 Luis Reyes · Jun 17, 2026 Luis Reyes · May 29, 2026 Luis Reyes · May 28, 2026 Dave McQuilling · Jun 18, 2026 Luis Reyes · Jun 18, 2026 Luis Reyes · Jun 18, 2026 Luis Reyes · Jun 18, 2026 Luis Reyes · Jun 18, 2026 Autonotion is the English-language automotive editorial by Autonocion.com — car news, reviews, and industry analysis for American readers. Other links Company Subscribe Get the latest car news in your inbox: By submitting your email you allow autonocion.com to send you news or promotions. More info
Solar panels, park improvements, and transportation safety are just a few of the county projects receiving funding from the Maryland Board of Public Works this week. On Wednesday, the Maryland Board of Public Works approved a little over $8M for projects in five counties and Baltimore City. The majority of those funds – $6.7M – came from grants by the Maryland Department of the Environment, with $6.5M of that going to Baltimore County for potable water infrastructure improvements. Another notable distribution went to Prince George’s in the amount of $1.1M from Program Open Space funds for the acquisition of eight acres of waterfront property to expand the Patuxent River Park. The remaining funds came from prior year capital budget allocations and the Recreation Communication Boards (RCB) Pilot Program. See all county projects below. Baltimore City Baltimore County Howard Prince George’s St. Mary’s Somerset
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Mongolia’s Ministry of Energy has kicked off a tender for five solar-plus-storage projects. The independent power producer (IPP) projects are set to have a combined solar capacity of 110 MW connected to 52 MW/188 MWh of battery energy storage systems (BESS). The invite to tender splits the procurement exercise into five sites, three of which are located in Mongolia’s western region, with the remaining two situated in the country’s eastern region. The government has identified and secured land for each auction site. The first site will encompass 10 MW of solar alongside a 10 MW/20 MWh BESS in the Bayankhongor province, while the second covers a 20 MW solar plus 10 MW/40 MWh BESS in the Bayan-Ulgii province, both to be built on 60 hectares of land. The third site encompasses a 40 MW solar plus 20 MW/80 MWh project in the Uvs province to be developed on 100 hectares of land. The fourth site, located in the Sukhbaatar province, will host a 10 MW solar plus 2 MW/8 MWh BESS on 35 hectares of land while the fifth site, in the Dornod province, will be home to a 30 MW solar plus 10 MW/40 MWh BESS on 90 hectares of land. Chosen developers will be responsible for the design, finance, construction, operation and maintenance of the solar-plus-storage facilities under an IPP structure. Each of the sites will be connected to existing grid substations. The tender starts with an expression of interest stage, with developers eligible to apply for both the western and eastern lots. The ministry has said it reserves the right to procure through a single competitive auction covering all sites, or through separate competitive auctions for individual sites or groups of sites. The deadline to submit expressions of interest is August 16, with a request for proposals currently scheduled during the second half of the year. Mongolia’s cumulative solar capacity stood at 129 MW by the end of 2025, according to figures published by the International Renewable Energy Agency (IRENA), a decrease on the 143 MW reported at the end of 2024. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: [email protected]. Comments Please login to comment The June issue of pv magazine Global is out now! Available in print and digital – get your copy today! Thursday, July 9, 2026 11:00 am – 12:30 pm CEST, Berlin, Paris, Madrid Thursday, June 18, 2026 2:00 pm – 3:00 pm CEST, Berlin, Paris, Madrid Be part of the high-level European conference on solar and energy storage, exploring bankable BESS projects, warranties, and energy management for residential and C&I sectors Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects. April 01 – August 31, 2026 A two-day conference in Austin, Texas, bringing together leaders in US solar manufacturing, equipment specification, and factory execution. Saudi Arabia is accelerating its clean energy transition—join the SunRise Arabia Clean Energy Conference 2026 in Riyadh to explore how solar PV and energy storage are powering its digital economy. Showcase your brand across all our platforms: from 13 websites in 7 languages to our magazines, daily newsletters, industry events and more. Reach your audience the right way! We are participating in Intersolar 2026 again this year! Visit us at our Booth Hall 2 A2.250 to discuss the latest trends within the photovoltaic industry with the pv magazine team. June 23-25, 2026 | MUNICH, GERMANY
Chinese solar cell and module manufacturer Aiko has signed a 1.2GW module supply deal with Infinity Power to supply modules for the latter’s Nefer Menya solar-plus-storage project currently under development in Egypt. Thea announcement was made at the African Energy Forum, which is currently underway in Cape Town, South Africa, and the project will consist of 1.2GW of solar PV capacity plus a 600MWh battery energy storage system (BESS). Infinity Power is a joint venture owned by Egyptian renewable energy developer Infinity and UAE state-owned developer Masdar, and the Nefer Menya project has received financing from the European Bank for Reconstruction and Development (EBRD), which increased its equity stake in Infinity last year. Get Premium Subscription The EBRD has also awarded a loan to a different Egyptian solar-plus-storage project, the 200MW Benban project, which is under development by Infinity Power and HAU Energy. “This project pushed us to look beyond standard module specifications,” explained Omar Magdy, senior procurement manager at Infinity Power. “Aiko demonstrated not only superior technical performance but also a deep understanding of the operational challenges unique to this region.” Aiko will supply its all-black all-back-contact (ABC) modules to the project, and noted that these modules would help tackle some of the “operational challenges” associated with working in Egypt’s desert environment. The company listed high solar irradiance, high temperatures and “persistent sand abrasion” as challenges that would have to be overcome during project deployment. Last year, experts from the EDWA R&D Center in Dubai wrote a piece for PV Tech Premium in which they explained why, despite the considerable potential to deploy large utility-scale solar projects in desert environments, there are environmental challenges that have proven difficult to overcome. They estimate that the degradation rate of PV modules in desert environments can be as much as 1.25 percentage points higher than those in “milder climates”. Aiko develops ABC technology, and this year announced plans to invest around US$243 million to support its manufacturing of ABC cells, including the conversion of a 5GW passivated emitter rear contact (PERC) manufacturing facility in China to ABC production. The company has also been involved in some of the technical ‘lawfare’ that has affected much of the solar sector this year, which culminated in the signing of a licencing agreement with Singapore-based manufacturer Maxeon for its back contact (BC) cell and module technology patents.
Perovskite PV specialist Oxford PV and German research institute Fraunhofer ISE have unveiled a new module prototype combining Oxford PV’s tandem perovskite-silicon cells with Fraunhofer’s matrix shingle interconnection technology. Ahead of Intersolar Europe in Munich next week, where the new design will be showcased, the two organisations said they had achieved a 25.6% efficiency across two prototype versions of the module. Get Premium Subscription Stefan Glunz, head of photovoltaics at Fraunhofer ISE, explained that in the new design, Oxford PV’s tandem cells are cut into shingles, electrically connected using conductive adhesive and encapsulated. The tandem modules are glass-glass with edge sealing to protect the moisture-sensitive solar cells. “We are delighted to be able to combine two high-tech approaches from Europe in this PV module,” added Glunz. Ed Crossland, chief technology officer at Oxford PV, highlighted the two organisations’ complementary technologies. “Our tandem technology and the shingle interconnection work well together technologically,” he said. “Due to the lower current densities of the perovskite-silicon solar cells, they can be cut into wider strips, which increases productivity.” Crossland explained that tandem solar cells achieve higher voltages and efficiencies than conventional cells, while the current is lower due to its distribution across two sub-cells. This lower current density helps reduce resistive losses within the PV module. “At the same time, the adhesive interconnection of the Matrix shingle technology is a low-temperature process and requires no copper connectors,” he added. Reducing the usage of copper connectors can reduce operating costs and reduce stresses in the module construction. The new design has been deployed in two prototype modules—a 491W rooftop version with an area of 1.92 square metres and a 546W bifacial model covering 2.13 square metres. Both achieved an efficiency of 25.6% across the entire module area, the organisations said. In resnpose to a question from PV Tech, Crossland said the prototype module had been constructed in a way “fully compatible with mass production”. “Oxford PV’s HyPERcell cell technology is compatible with multiple interconnection approaches. Our current released product is 25% with a ten-year lifetime but continual improvements in production cell and module technology will deliver our roadmap of 27% with a 20-year lifetime in 2027, independent of module design. We will release a product with 26% efficiency this year,” he said. Tandem modules combining perovskite and especially silicon PV technologies are widely seen as the next evolutionary leap in the solar technology roadmap. Adding a perovskite layer to a silicon cell can significantly boost conversion efficiency beyond the theoretical limits of silicon-only cells. Oxford PV has been a leading actor in developing tandem technology and moving it towards commercial deployment through its pilot production facility in Brandenburg an der Havel, Germany. Fraunhofer’s Matrix Shingle technology bonds solar cell strips together with electrically conductive adhesives in an overlapping, staggered pattern like roofing shingles. This enables complete coverage of the entire module surface and high tolerance to partial shading. The matrix arrangement allows current to flow around the shaded areas, resulting in up to twice the power to be generated compared to conventionally connected PV modules, depending on the level of shading, Fraunhofer said. The new PV modules were developed as part of the ‘HoTSun’ research project, funded by Germany’s Federal Ministry for Economic Affairs and Energy. Both will be on display in Munich next week. Innovations in solar cell design will be a topic of conversation at Solar Media’s PV CellTech USA Conference in San Francisco, on 13-14 October 2026, with a session on trends in global cell research and development on the first day of the event. Read the full agenda here and book tickets on the event website.
New research conducted by residential energy data platform 257, in collaboration with the Smart Energy Consumer Collaborative (SECC), has revealed that homebuyers pay measurable premiums for homes with energy upgrades. Specifically, the researchers found that home listings that explicitly mentioned rooftop solar panels sold for 2% higher than comparable homes, equating to a $10,000 premium, based on the median sales price of $557,000. Listings that mentioned heat pumps were also associated with higher sale prices of between 0.6% and 1%, on average, resulting in price premiums of between $2,300 to $3,900 on homes with a median sales price of $399K. Despite the findings of price premiums for energy upgrades, researchers found that only 8.3% of the 2025 home listings they surveyed mentioned energy-efficient assets. However, the share of listings mentioning energy efficiency upgrades nearly tripled between 2015 and 2025, suggesting that the practice represents a growing trend. In total, the survey considered 143 million home listings nationwide from 1995-2025, but whittled the pool of homes used for the report down to those with solar and/or heat pumps sold between 2024 and 2025, analyzing the difference in sale prices between those that explicitly mentioned the upgrades and those that didn’t. The findings are included in a new report from the SECC entitled “Home Buying in the Energy Transition,” which looks at broader trends in consumer interest in energy efficiency and clean energy technologies, including which information is readily available, how important those factors are to home buyers and whether real estate agents are able to promote those features and educate consumers through the listings and tours. The report finds that, while consumers say they value energy efficiency, they are rarely presented with key information while evaluating prospective homes. Furthermore, while 84% of agents reported being somewhat or very familiar with energy efficiency, far fewer of them expressed confidence in being able to explain the benefits to consumers. In addition to the disconnect between familiarity and confidence in explaining, the SECC data shows that agents and consumers differ greatly in the level of importance the role of energy efficiency plays in the home buying process. While 84% of consumers reported energy efficiency being somewhat or very important, just 34% of Realtors said the same. In addition, 60% of agents said that “limited client interest” prevented them from discussing energy efficiency with their clients, suggesting a disconnect between what consumers believe and what agents understand about their desires Comments Please login to comment The June issue of pv magazine Global is out now! Available in print and digital – get your copy today! Thursday, July 9, 2026 11:00 am – 12:30 pm CEST, Berlin, Paris, Madrid Thursday, June 18, 2026 2:00 pm – 3:00 pm CEST, Berlin, Paris, Madrid A two-day conference in Austin, Texas, bringing together leaders in US solar manufacturing, equipment specification, and factory execution. Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects. April 01 – August 31, 2026 pv magazine USA hosts its third multi-day virtual event on advancing U.S. solar and energy storage markets, covering financing, supply chains, and distributed energy’s role in grid resilience.
Agree & Join LinkedIn By clicking Continue to join or sign in, you agree to LinkedIn’s User Agreement, Privacy Policy, and Cookie Policy. 200,285 followers India’s #indigenous#SolarCell manufacturers are expected to meet around half of the country’s overall solar cell demand this fiscal. @navneetvats0009 https://lnkd.in/g58ANvUB To view or add a comment, sign in 200,285 followers Create your free account or sign in to continue your search
SINCE 1819 Unlock unlimited access to all stories SINCE 1819 HomeNews Article Kingsway Solar Farm Ltd has withdrawn its Development Consent Order (DCO) application for a huge 500-megawatt solar farm in the Cambridgeshire countryside – but it has not abandoned the controversial plans. Instead, the company plans to resubmit its application after addressing “key issues and information requirements”. The company said its decision to withdraw plans for the solar farm, which could provide power for about 175,000 homes annually, followed “discussion with the Planning Inspectorate”, which would have examined the application. It follows the Cambridge Independent’s report last week on how the consultation carried out by the company had been heavily criticised by planners at both East Cambridgeshire District Council and South Cambridgeshire District Council for lacking detail and key information. Kingsway Solar Farm is proposed for 3,000 acres of farmland between Burwell and Balsham, with 15km of overhead lines between Brinkley and Burwell, and pylons every 300 metres or so. Communities in the area have argued it will industrialise the countryside and have objected to the scale of the proposals. After withdrawing its DCO application, Kingsway Solar Farm Limited said it “remains determined to deliver the best possible project which considers all the potential impacts as effectively as possible”. Its statement continued: “We intend to work with the Planning Inspectorate and key stakeholders to understand and address key issues and information requirements, in order to bring forward the strongest possible proposals for this critical national project. The intention is to resubmit the DCO Application once these issues have been reviewed and appropriately addressed, and a timeline for that will be provided to all stakeholders as soon as possible.” The company argues the solar farm would make “a significant contribution towards increasing national energy security” and it is designated as a Nationally Significant Infrastructure Project (NSIP). David Vernon, head of NSIP Projects at Kingsway Solar Farm Ltd, said: “Kingsway Solar is a project designed to address national need for home grown, affordable, clean and reliable energy. We have been working extremely hard over the last few years to develop our proposals and bring forward a high quality scheme that meets those objectives while managing any impacts to the greatest degree possible. “We intend to re-engage with stakeholders and are committed to addressing any outstanding issues and strengthen our proposals. We look forward to working with local and national stakeholders in the coming weeks as we look to resubmit our DCO Application in due course. “I appreciate everyone’s patience and continued engagement as we go through this next phase.” The scheme would require co-located battery energy storage systems (BESS) and inter-array connections to link together the parcels of land on which the solar panels would be located. Nick Acklam, a Reach parish councillor who has been involved in community objections to the scheme, was pleased by news of the withdrawal. “I suspect that consensus among statutory consultees that the proposal was poorly constructed and consultation over its plans was inadequate will be factors. The strength of community opposition will have been another consideration,” he said. “Of course this does not mean that Kingsway has gone away – it could resubmit a revised application in the future but there is no doubting that this is good news for the 21 parishes that would have been damaged by the proposal and evidence that sensible, well-organised and well-argued community action can work.” Nominate now Guide to property in the region Sharing business intelligence
The Solar Energy Industries Association (SEIA) has released a new interactive map, detailing solar energy’s place — or lack thereof — on U.S. prime farmland. The new map program comes at a crucial moment, as Farm Bill negotiations in the U.S. Congress have caused greater scrutiny than ever on agrivoltaics-related solar projects. According to SEIA, the map shows that solar takes up a “remarkably small” percentage of farmland throughout the U.S., coming in at about 0.07% of farmland in the country. SEIA president and CEO Tim Pawlenty, who took over for interim president Darren Van’t Hof on June 15, says the new map will, above all, provide context. As misinformation continues to swirl around the perceived dangers or risks of agrivoltaics, the map showcases the ability for farming and renewable energy plants to coexist, he says. “America depends on our land to grow our food, build our communities, and power our lives,” he says. “Responsible land use means balancing all of those needs. This map helps provide important context by showing that solar and agriculture can thrive together. Solar development uses a very small amount of farmland compared to many other common land uses, while also delivering affordable energy, local tax revenue, and reliable income for farmers and landowners.” According to SEIA’s map, there are currently zero states where solar takes up more than 0.05% of prime farmland. In terms of total land, solar’s share of things is even paltrier than when looking at farmland, coming in at just 0.04% in total. Additionally, nearly every state in the Union has far more abandoned prime farmland, than prime farmland that is currently in use. Around the country, there are 43 acres of abandoned farmland for every acre that gets used, SEIA says. Comparing solar’s share of prime U.S. farmland to other non-essential puts the small land risk of agrivoltaics even further in perspective. New suburban developments since 2014 alone have used up roughly six times more prime farmland around the country than solar projects do. Golf courses around the U.S. take up 2.6 times the amount of prime farmland as solar arrays do. “Communities, landowners, farmers, local officials, and solar and storage developers all share an interest in responsible land use,” the trade association says. “SEIA has developed extensive land use resources, research, and best practices to help communities make informed decisions about responsible solar and storage development.” SEIA also notes than unlike suburban development, golf courses, and other permanent farmland use fixtures, solar arrays can be decommissioned and taken down at the end of their lifespan. In turn, “thousands” farmers and other private landowners have chosen dual-use solar as a second revenue stream, while also passively helping to power local communities.
Solar Power World By Kelly Pickerel | In the heart of the Emma community just outside Asheville, North Carolina, a transformation is taking place that goes far beyond hardwire and wires. While the transition to renewable energy is often seen as a luxury, a partnership between Sugar Hollow Solar,PODER Emma and Footprint Project is providing clean energy as a vital tool for innovative community resilience and displacement prevention. The trio of organizations recently completed an array of solar installations that represent a significant leap forward in combining affordable housing preservation with environmental justice. PODER Emma, a mobile home community, has long served as a resource for locals, utilizing cooperative ownership to protect families from displacement. By securing land collectively, they ensure that legacy residents who built the Emma neighborhood get to remain. This partnership with Sugar Hollow Solar and Footprint Project introduces a new layer of security: energy independence. By generating their own power, these communities are no longer at the mercy of rising utility rates, allowing financial resources to remain within the neighborhood. “We are excited to take this step for clean energy,” said Alan Ramirez, Board Member and Secretary of La Esperanza, the real estate co-op for PODER Emma. “During the hurricane, La Esperanza was our hub for resources and resilience. With solar power, we are saving our resources, producing power and feeling stronger than ever.” Fifteen solar panels were installed on custom-built porch roof structures for the mobile homes and a 46-kW system was installed on the roof of PODER’s community hub. These projects were made possible by the Repower WNC Fund, a Sugar Hollow Solar initiative supported by the Amicus Solar Cooperative, sub-grants for equipment and labor and PV panel donations by Footprint Project, donations by IronRidge and Invest Appalachia grants. As Asheville looks toward a more sustainable future, the collaboration between Sugar Hollow Solar, PODER Emma and Footprint Project stands as a blueprint for equitable energy. Communities impacted by development are often left out of the entire process. These projects have helped highlight that when a community is given the information and tools needed, brilliant and innovative things can happen. By addressing the disproportionate percentage of income spent on utilities in lower-income communities, PODER Emma ensures that the Emma community remains in a place where they can thrive. News item from Sugar Hollow Kelly Pickerel has more than 15 years of experience reporting on the U.S. solar industry and is currently editor in chief of Solar Power World. Email Kelly.
Indian credit ratings, research and risk analytics company Crisil expects domestically manufactured solar cells to account for half of India’s total demand in fiscal year 2026–27, which runs from 1 April 2026 to 31 March 2027, up from about one-fourth in the previous fiscal year. The outlook is based on capacity expansion plans announced by domestic solar module and cell manufacturers, supported by policy measures aimed at reducing reliance on imports and accelerating local manufacturing. The increase in domestic share is expected to be driven by the government’s push for localization, alongside a sharp ramp-up in solar cell manufacturing capacity. However, rapid capacity additions could pressure utilization rates and realizations, potentially extending payback periods for manufacturers. The projections factor in India’s policy framework, including the Approved List of Models and Manufacturers (ALMM) introduced by the Ministry of New and Renewable Energy (MNRE), which was later extended upstream through the Approved List of Cell Manufacturers (ALCM) to reduce dependence on imported solar cells. Ministry of New and Renewable Energy implemented ALMM from 1 April 2024. The ALCM framework is expected to become mandatory from June 2026 for utility-scale projects with bid submissions after 31 August 2025, and for net-metering and open-access projects commissioned after 1 June 2026. Residential rooftop solar under the PM Surya Ghar: Muft Bijli Yojana is exempt until 31 March 2027. “The ALCM will sharply reset India’s solar cell supply mix. Domestic supply will gain share and meet around half of the 60–65 GW demand this fiscal, with imports making up the rest,” said Manish Gupta, deputy chief ratings officer at Crisil. According to the report, demand for locally made cells will be driven by new utility-scale bids, net-metering and open-access projects, and government-backed programmes such as the Kisan Urja Suraksha evam Utthaan Mahabhiyan (KUSUM). Imports will largely serve the pipeline of already bid-out utility-scale projects submitted before the 31 August 2025 cut-off. As that pipeline is completed, import dependence is expected to decline materially from the following fiscal year. With rising demand and policy support, manufacturers are investing in new solar cell capacity. Crisil expects India’s cumulative solar cell manufacturing capacity to nearly double to 60 GW by the end of fiscal 2026–27, with further additions likely thereafter. The rapid buildout, however, could weigh on project returns. “The surge in solar cell capacity will redraw project economics. Capacities commissioned by the end of this fiscal could see payback periods stretch by 1–2 years, compared with the 4–5 years seen for early movers integrating backward into solar cell manufacturing,” said Ankit Hakhu, director at Crisil. He added that early integrated players benefited from higher premiums and utilisation rates of 50–60% after stabilisation, advantages that are expected to narrow as additional capacity comes online. Payback timelines are increasingly important in the sector given rapid technology shifts, which can shorten asset life cycles, particularly where imported inputs add margin volatility. Crisil also noted that manufacturers moving further upstream into ingot and wafer production—segments currently heavily import-dependent—could see improved returns once the government implements the proposed ALMM-III framework for ingots and wafers, expected from June 2028. A key risk remains delays in power purchase agreement signings, which could weaken near-term solar module demand. The MNRE has also formed an expert committee to review exemption requests under the ALCM framework for certain net-metering and open-access projects where modules have already been installed or where developers have made substantial progress. Any material exemptions could affect demand for domestically produced solar cells.
This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: [email protected]. Comments Please login to comment The June issue of pv magazine Global is out now! Available in print and digital – get your copy today! Thursday, July 9, 2026 11:00 am – 12:30 pm CEST, Berlin, Paris, Madrid Thursday, June 18, 2026 2:00 pm – 3:00 pm CEST, Berlin, Paris, Madrid Be part of the high-level European conference on solar and energy storage, exploring bankable BESS projects, warranties, and energy management for residential and C&I sectors Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects. April 01 – August 31, 2026 A two-day conference in Austin, Texas, bringing together leaders in US solar manufacturing, equipment specification, and factory execution. Saudi Arabia is accelerating its clean energy transition—join the SunRise Arabia Clean Energy Conference 2026 in Riyadh to explore how solar PV and energy storage are powering its digital economy. Showcase your brand across all our platforms: from 13 websites in 7 languages to our magazines, daily newsletters, industry events and more. Reach your audience the right way! We are participating in Intersolar 2026 again this year! Visit us at our Booth Hall 2 A2.250 to discuss the latest trends within the photovoltaic industry with the pv magazine team. June 23-25, 2026 | MUNICH, GERMANY
A few months ago, SunEnergyXT introduced the 500 Pro Series, a new all-in-one energy storage system for balcony solar systems and photovoltaic (PV) installations. Ahead of the upcoming ees Europe 2026 trade fair in Munich, the manufacturer formerly known as SunLit Solar is expanding the lineup with three additional products: the SunEnergyXT PowerBox, the SunEnergyXT 500 Pro AC Core, and the Smart Wallbox. The new PowerBox allows three-phase operation of more than three master storage units from the 500 and 500 Pro Series. This makes it possible to operate up to nine units in parallel and distribute them across the three phases L1, L2, and L3. Total system output can reach up to 21.6 kW, making it capable of supplying even high-consumption loads such as heat pumps and EV charging stations. In addition, when combined with a compatible Automatic Transfer Switch (ATS) for automatic switching between grid-connected and island operation, the system can provide a fully functional backup power solution. The new Smart Wallbox can, for example, be powered by the PowerBox’s output of up to 21.6 kW. It supports three-phase charging of electric vehicles at up to 11 kW (maximum 16 amps) via a Type 2 charging cable. The wallbox features an integrated RFID reader for access control and user-specific authorization. It is also compatible with the SunEnergyXT app, enabling coordinated management of charging, energy storage, and self-consumption, while allowing charging schedules to be aligned with the availability of self-generated solar power. The third new product is the SunEnergyXT 500 Pro AC Core. It complements the existing all-in-one solution and is a purely AC-coupled battery storage system. The home energy storage unit is well suited for retrofitting existing photovoltaic systems and can also be particularly attractive when used in conjunction with dynamic electricity tariffs. The SunEnergyXT 500 Pro AC Core features a bidirectional inverter with 2,400 W charging and discharging power, along with 5 kWh of storage capacity. If required, capacity can be expanded to up to 30 kWh by adding up to five additional battery modules. Another noteworthy feature is that the integrated MPPTs already built into the unit for direct solar module connection are disabled only at the software level. If needed, they can be activated later for an additional fee. SunEnergyXT
This bill is one of 12 solution-oriented energy bills PEC either authored, informed or advocated for in the General Assembly that have been signed into law. PEC worked on these practical legislative proposals with partners before the 2026 General Assembly session, laying the groundwork for accelerating underutilized small-scale, distributed generation and storage opportunities in Virginia. These bills contribute to the Commonwealth’s clean energy future while also enabling energy independence for more Virginians. “The topic of agrivoltaics is one that has been top of mind for me for years,” said Spanberger, “because it has always been a question of how is it that we can ensure that our communities–and importantly our farmers–have the ability to keep land in production, but also the option to leverage the technology that can help them offset their on-farm costs and also allow them to be leaders. “By establishing clear enforceable definitions of agrivoltaics and code of Virginia, we are protecting farmers. We are making clear that the use of agrivoltaics prioritizes agricultural productivity, keeps land in production for the life of the solar array and is part of an existing farm business.” Until now, Virginia has lacked an official definition for agrivoltaics. This is critical, not only to build policy and incentive structures for such projects, but also to avoid poorly developed agrivoltaics – which can undermine the future of this promising approach. Working alongside the Virginia Farm Bureau, PEC helped develop an official definition for agrivoltaics that will ensure dual use solar projects take best management practices into account. This bill, which garnered strong bipartisan support and was a priority bill for the Governor, defines agrivoltaics to mean: “…the intentional co-location of agricultural production and solar energy generation on the same land that: PEC’s Community Farm demonstrates a real-world example. It also has full battery backup, which allows the farm to run fully on solar and battery in case the electricity grid goes down. When multiple farms, businesses and homes use battery backup, the energy they produce and store together can function as a “virtual power plant,” furthering the potential for decentralized power generation, mitigating new transmission and generation impacts, and compensating those owners for their contributions to the power grid. “We’re proud to convene this bill signing at the site of the first crop-based agrivoltaics project in Virginia,” said PEC Senior Energy & Climate Advisor Ashish Kapoor. “Behind me, you can see kale, lettuce, beets, broccoli, garlic and more, growing under solar panels that are generating energy to reduce this farm’s electricity bill. “In fact, we have had no electric bill this year. This site provides a model for other farms in Virginia, and we hope farmers who want to achieve more energy independence will consider integrating solar energy production into their crop production. Virginia has 39,000 farms. If ten percent of those farms installed an agrivoltaics project that produced just 1 megawatt of power on a few acres, we could produce the equivalent power of four nuclear power plants.” The agrivoltaics definition bill also provides a critical foundation for a future stakeholder group that will develop potential incentives to advance agrivoltaics in the Commonwealth. In addition, the definition can guide regulation of agrivoltaics in other solar policies.
Kosol Energie has commissioned a 31 MW (DC) solar PV project for Gujarat State Electricity Corporation (GSECL) in Kutch, Gujarat, under the state's Renewable Energy Policy and Green Energy Mission. June 18, 2026. By Mrinmoy Dey Renewable Expansion Without Storage will put Increasing Stress on the Grid: Hiren Pravin Shah Integrated EPC Solutions are IB Solar’s Strongest Differentiator: Aakshi Mahajan Transformers to Power Energy Future as Grid Modernisation Accelerates, Says Satyen Mamtora Future of Renewable Infra Will Be Built on Resilient Structures, Not Cheapest Ones: Vedant Goel AI, Digitalisation Will Drive Next Phase of India’s Energy Transition: Schneider’s Udai Singh
In the heart of the Emma community just outside Asheville, North Carolina, a transformation is taking place that goes far beyond hardwire and wires. While the transition to renewable energy is often seen as a luxury, a partnership between Sugar Hollow Solar, PODER Emma and Footprint Project is providing clean energy as a vital tool…
Perovskite solar module manufacturer Oxford PV announced it achieved a power conversion efficiency of 25.6% for a perovskite-silicon tandem solar module relying on a shingled architecture developed by Germany’s Fraunhofer Institute for Solar Energy Systems (Fraunhofer ISE). “For the first time, the two organizations have successfully combined Oxford PV’s perovskite-silicon tandem solar cells with Fraunhofer ISE’s Matrix Shingle module technology,” Ed Crossland, CTO of Oxford PV, told pv magazine. “Beyond the efficiency gains, the combination also reduces resistive losses, removes the need for copper interconnects, and improves resilience under partial shading – all key considerations as the industry looks to reduce costs while increasing energy yield.” “The module presented is a prototype, but it is built using standard production cells and in a way that is fully compatible with mass production. Our current tandem modules are already delivering efficiencies of 25% with 10-year lifetime today, and this result builds directly on that. We continue to make progress along our roadmap, with a 26% product planned for release this year and a path to 27% with extended lifetimes by 2027,” Crossland added. The Matrix Shingle approach improves conventional solar module interconnection by replacing traditional busbar-and-ribbon architectures with a dense, overlapping cell layout. In this method, photovoltaic cells are precision-cut into narrow strips and reconfigured into a shingled pattern, similar to roof tiles. Adjacent strips overlap slightly and are bonded using electrically conductive adhesive (ECA), which provides both mechanical adhesion and electrical interconnection between neighboring cell segments. By eliminating soldered interconnect ribbons and busbars, the architecture removes inactive spacing that would otherwise block incoming light. As a result, optical shading losses are significantly reduced and a larger fraction of the module surface becomes active photovoltaic area, improving packing density. The reduction in metallization shading also enhances current collection efficiency, as more of the cell surface is exposed to sunlight. In addition, the shingle configuration shortens current pathways and distributes current more uniformly across the module, which can reduce resistive losses and localized heating. The use of ECA instead of high-temperature soldering also reduces thermal stress during assembly, helping to preserve cell integrity and potentially improve long-term reliability. Overall, the Matrix shingle approach increases module power density by combining higher active-area utilization with improved electrical and optical performance. “We are delighted to be able to combine two high-tech approaches from Europe in this PV module,” said Stefan Glunz, head of photovoltaics at Fraunhofer ISE. “To achieve this, we have cut the solar cells from Oxford PV into shingles, arranged them in a matrix structure, electrically connected them using conductive adhesive, and then encapsulated them.” Two tandem glass-glass modules were built with this configuration and edge sealing to protect the moisture-sensitive solar cells: a 491 W rooftop module with an area of 1.92 m², and a 546 W bifacial module with an area of 2.13 m². “Both achieved an efficiency of 25.6% across the entire module area,” Oxford PV’s spokesperson said. “Our tandem technology and the shingle interconnection work well together technologically,” said Ed Crossland, chief technology officer at Oxford PV. “Due to the lower current densities of the perovskite–silicon solar cells, they can be cut into wider strips, which increases productivity. Tandem solar cells achieve significantly higher voltages and efficiencies than conventional cells, while the current is lower due to distribution across two sub-cells. This lower current density is beneficial, as it helps reduce resistive losses within the PV module. At the same time, the adhesive interconnection of the Matrix shingle technology is a low-temperature process and requires no copper connectors.” Oxford PV unveiled its first perovskite-silicon tandem solar module with 26.9% efficiency in June 2024. A few months later, the company announced the commercial launch of perovksite-silicon tandem modules in the United States. It began working on its perovskite tandem solar modules in 2014 and claims to have a “clear roadmap” to bring the technology to over 30% efficiency. Comments Please login to comment The June issue of pv magazine Global is out now! Available in print and digital – get your copy today! Thursday, July 9, 2026 11:00 am – 12:30 pm CEST, Berlin, Paris, Madrid Thursday, June 18, 2026 2:00 pm – 3:00 pm CEST, Berlin, Paris, Madrid A two-day conference in Austin, Texas, bringing together leaders in US solar manufacturing, equipment specification, and factory execution. Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects. April 01 – August 31, 2026 pv magazine USA hosts its third multi-day virtual event on advancing U.S. solar and energy storage markets, covering financing, supply chains, and distributed energy’s role in grid resilience.
Thank you for visiting nature.com. You are using a browser version with limited support for CSS. To obtain the best experience, we recommend you use a more up to date browser (or turn off compatibility mode in Internet Explorer). In the meantime, to ensure continued support, we are displaying the site without styles and JavaScript. Advertisement npj Clean Energy has APC waivers available that can be allocated upon acceptance on an ad-hoc basis. For additional information, contact the Journal Publisher, Ashwini Jamthe. npj Clean Energyvolume 2, Article number: 8 (2026) Cite this article 1538 Accesses 7 Altmetric Metrics details Photovoltaic solar energy represents a highly promising solution for Morocco, benefiting from abundant and consistent sunlight, despite persistent challenges such as land scarcity and high temperatures that affect efficiency. Installing solar photovoltaics on existing dams offers an attractive and sustainable alternative, as they enhance overall renewable energy production, reduce evaporation, and benefit from existing electrical infrastructure. This approach contributes to the optimization of water and energy resources. This paper evaluates the techno-economic feasibility of floating photovoltaic (FPV) systems on 58 Moroccan dams, considering water surface availability, evaporation rates, potential energy production, panel tilt angles, associated costs, and various floating platform configurations. This national-scale evaluation provides new insights into FPV deployment, offering essential data to support Morocco’s renewable energy transition. The results indicate that the total surface area of the monitored dams is approximately 433 square kilometers, with an estimated annual water loss of around 909.458 million cubic meters due to evaporation. The analysis of panel tilt angles suggests that 31° may be optimal for energy production, while lower angles, such as 11°, also remain viable, offering a better balance between energy generation and water conservation. It was concluded that covering just 1% of the total surface area of all monitored dams could make a substantial contribution to Morocco’s energy needs, providing a rapid return on investment. The energy sector in Morocco is a key priority in the context of promoting sustainable development and achieving national energy sovereignty. The country has been making vigorous efforts to accelerate the transition to renewable energy, aiming to reduce dependence on traditional energy sources and achieve the goals of the national energy strategy. In this context, the announcement of the ambitious target of reaching 52% renewable energy in the national energy mix by 2030 reflects the country’s determination to move towards a clean and sustainable energy future (Fig. 1)1. Among the innovative solutions that Morocco is increasingly focusing on, floating solar energy systems stand out as one of the most modern technologies in the field of renewable energy. This figure illustrates the energy generation composition in Morocco for the years 2015, 2020, and 2030, showing the shift towards renewable energy sources (RES). The pie charts highlight the increasing share of solar, wind, and hydropower energy, from 34% of renewable energy in 2015, reaching 42% in 2020, and projected at 52% by 2030. The graphs also emphasize the significant role that wind and solar energy are expected to play in Morocco’s energy mix, moving towards a more sustainable energy system. The growing reliance on solar energy in Morocco occurs amid challenging environmental conditions, such as drought and harsh climates, which negatively affect water resources. Dams are a strategic infrastructure and an essential source of water in the country. Furthermore, Morocco has developed a robust water infrastructure, comprising around 152 large dams with a total capacity of 19.9 billion m³ in 2023, according to the Ministry of Equipment and Water. Despite their importance for water supply and irrigation, these dams face increasing evaporation due to rising temperatures and declining rainfall2. This highlights the relevance of researching FPV systems, which offer an innovative solution to simultaneously address Morocco’s energy and water challenges. The main advantage of FPV systems is that they do not require agricultural or usable land, making them an ideal choice, especially in densely populated areas or areas where land use is highly competitive3. This system involves installing floating solar panels on large water bodies, such as dams and lakes, enabling the generation of clean electricity without impacting terrestrial ecosystems4. Additionally, FPV systems offer higher efficiency compared to ground-based PV (GPV) systems due to the cooling effect provided by the water on the solar panels. Studies by El Hammoumi et al. (2021)5,6 Skoplaki and Palyvos (2009)7, Rahman et al. (2015)8 and Liu et al. (2017)9 have demonstrated that the production efficiency of FPV systems can be up to 2% higher than that of GPV systems, which enhances energy production and improves the profitability of these floating solar systems. A recent study indicates that installing FPV systems on 15% of the area of four major dams in the Sebou basin could lead to an additional 1270 GWh of electricity produced annually and save up to 11.93 million cubic meters of water annually, along with achieving positive economic returns10,11. Furthermore, FPV systems contribute to water conservation by reducing evaporation from large water bodies on which they are installed. Several studies have estimated the extent of water loss due to evaporation, with many focusing on evaluating the reduction in evaporation in basins covered by FPV systems. For example, research conducted in Spain found that covering an irrigation reservoir with FPV panels led to a 25% reduction in water capacity12,13 Similarly, a large-scale nine-month experiment demonstrated the effectiveness of using floating solar panels to reduce evaporation from open water bodies in the studied semi-arid region. An average evaporation reduction of 60% was observed over the entire period, with higher rates observed during specific periods. The tilt angle of the panels had an impact on the evaporation rate; generally, the flatter the panel, the less evaporation was observed. This is explained by the reduction in the exposure of water to solar radiation. However, this conclusion could not be statistically verified14. Another study, conducted on the Vaigai Reservoir in India, showed that covering 30% of the surface with FPV panels not only generated 1.9 GWh of energy but also resulted in a significant water saving of 42,731.56 m³ annually. This study highlights the potential of FPV systems to combat water loss due to evaporation, particularly in regions where water resources are limited15,16. Research such as that conducted by Rosa-Clot et al. (2017)17, Taboada et al. (2017)18, and Redon Santafe et al. (2014)12 has shown that FPV systems can significantly reduce water evaporation, which is especially beneficial in dry climates where water is a limited resource. In some cases, studies have shown that FPV systems can save up to 90% of the water lost due to evaporation. Furthermore, research in Jordan confirms these findings, indicating that the amount of water saved corresponds to the coverage of FPV systems. However, it should be noted that both experiments conducted in Jordan used Class A coverage, which may not fully represent the true effect of FPV systems on large water basins, especially considering the typically low coverage of FPV panels19. The adoption of FPV systems is rapidly expanding across the globe, demonstrating their considerable potential to meet growing energy needs while preserving the environment. These innovative facilities can now be found in many countries, including the United States, Spain, Italy, China, Singapore, and South Korea20. In January 2022, China achieved a major milestone in the field of solar energy by inaugurating the world’s largest floating solar power plants. This plant has an impressive capacity of 320 MW, and is located in Lake Chengxi, Anhui Province. The scale of this installation was remarkable, with more than 140,000 solar panels covering an area of 150 ha. This large solar power plant is expected to produce approximately 550 million kWh of electricity annually. This colossal production is equivalent to the annual consumption of approximately 180,000 Chinese homes, highlighting the immense potential of floating solar energy to provide clean and sustainable electricity on a large scale21. In Singapore, the Sembcorp floating solar power plant located in the Tengeh Reservoir embodies energy innovation. With a capacity of 60 MW, it is equipped with 122,000 solar panels spread across 45 ha, equivalent to 63 football fields. Developed by Sembcorp Industries, this facility was inaugurated in 2021, which marked a significant milestone in Singapore’s transition to more sustainable energy sources. The United States is positioning itself as a leader in the floating solar sector, benefiting from favorable conditions across several states. With its generous sunshine and vast expanses of water, the country offers considerable potential for this emerging technology22. Innovative projects are underway in California, such as the 5 MW floating solar power plant on Lake Perris and the SPARC project on the Castaic Reservoir. Nevada is also exploring this path with the 1.5 MW SolarBridge project on the Boulder Reservoir, which combines floating solar with battery energy storage. Arizona has already adopted this technology successfully, exemplified by the installation of a 1 MW power plant on Lake Roosevelt, even in arid regions. Lake Mead, the largest man-made lake in the U.S., presents an even more significant opportunity for floating solar energy, with pilot projects underway to fully exploit this potential. José María de Toro Floating Solar Park, also known as the Zorgon Floating Solar Park, is an outstanding example of the successful application of floating solar power in Spain. Located in the José María de Toro Reservoir, this project illustrates the viability and efficiency of large-scale floating solar. Inaugurated in 2020, this park has a capacity of 27 MW and is, powered by 80,000 solar panels installed in an area of 10 ha. This achievement is a testament to Spain’s commitment to renewable energy and provides an inspiring example of other similar initiatives worldwide23. Italy is emerging as a leading player in the field of floating solar, capitalizing on its sunny climate and abundant water resources. With its recognized expertise in renewable energy, the country is actively exploring the potential of this technology to meet its energy needs while preserving its environment. Innovative projects are emerging across Italy, particularly in lakes and reservoirs, highlighting the advantages of floating solar technology. Notable examples include a 2.5 MW FPV installation on Lake Idro, a 1.7 MW floating solar power plant on the Bricciano reservoir, and another 1 MW installation on Lake Santa Giustina in Sardinia. These achievements demonstrate Italy’s commitment to sustainable energy transition and reinforce its emerging role as a leader in floating solar power in Europe24. South Korea is investing in floating solar energy to diversify its energy supply and to reduce its dependence on fossil fuels. FPV projects are emerging in artificial reservoirs and lakes, highlighting the potential of this technology for energy transition25. Notably, the 5.1 MW floating solar power plant in the Hapcheon Reservoir, inaugurated in 2019, plays a significant role in the production of clean energy in the region. Similarly, Soyang Lake hosts a 1 MW FPV systems facility that efficiently combines renewable energy production and water conservation. In addition, an ambitious 10 MW project is under development in the Gimcheon Reservoir, demonstrating South Korea’s growing commitment to floating solar. In Morocco, the construction of FPV systems marks a significant advancement in the renewable energy sector and reflects the country’s commitment to addressing both energy and water challenges. Notable initiatives include the first FPV plant in Africa, installed in Sidi Slimane with a capacity of 360 kW, and a 13 MW FPV project on the Oued Rmel dam in Tangier, developed in collaboration with the Ministry of Energy Transition and Sustainable Development. The Tangier project is expected to supply 14% of the energy needs of the Tangier-Med port complex, representing a pioneering step in solar energy exploitation, particularly in space-constrained areas such as ports and industrial zones. However, few studies have been conducted in Morocco on FPV systems. Existing research includes the first FPV prototype, designed to evaluate the performance of FPV compared to GPV systems5, as well as assessments of floating solar potential and water conservation through case studies on four hydroelectric dams10. Most previous studies have focused on limited regional areas; for instance, the analysis in the Sebou Basin10 examined only four major dams. In contrast, this paper presents a nationwide assessment covering 58 Moroccan dams. Its originality and main contribution lie in applying established models and techniques on a larger, national scale, providing a more comprehensive evaluation of the potential of FPV systems across the country. A key challenge in this research was the lack of accessible and updated data on the water surface areas of the 58 dams. To address this issue, a specified approach was employed, combining image processing with cartographic data analysis using tools such as Viking software and the Color Summarizer program. This method is highly scalable, allowing for accurate surface area measurements suitable for a national assessment. Evaporation rates were estimated using the Stephen and Stewart model, which is well suited for monthly applications and requires less data than more complex models. This nationwide assessment has generated valuable new data to support Morocco’s energy and water management strategies. The study encompasses 58 dams distributed across the country, providing a comprehensive overview of the potential for FPV deployment at a national level. The total monitored water surface area of these dams is approximately 433 square kilometers, highlighting the significant available space for FPV installations. The analysis estimates an annual water loss of around 909.46 million cubic meters due to evaporation. Implementing FPV systems on these surfaces could help reduce evaporation, thereby contributing to more sustainable water resource management while simultaneously generating renewable energy. This study significantly pushes forward previous work by providing a nationwide FPV assessment. Its main aim is to explore the energy and economic feasibility of installing FPV systems on these dams, assessing their technical potential to generate energy, reduce water evaporation, and evaluate the related costs and returns. The remainder of this paper is organized as follows. Methods section outlines the materials and methods used in this study. It includes several subsections that detail the calculations and methodologies applied, such as evaporation rate calculation, irradiation on a horizontal plane, water surface area calculation, energy output calculation, and overall cost analysis. Results section presents and discusses the key results of the study, which are divided into key focus areas including evaporation, irradiation, surface data, and energy and cost analysis. Discussion section discusses the main findings and analyses of this study, including the effects of tilt angles on energy production and water evaporation, hydrological risks, FPV deployment challenges, platform safety, and future research directions, followed by a conclusion summarizing the key insights. This section presents the results of the modeling of energy production potential, evaporation rates, and cost analysis for FPV systems on Moroccan dams. It is important to note that the figures presented are estimates based on theoretical models and aggregated data, and the study highlights a crucial need for validation by real data from operational FPV installations, along with a more detailed sensitivity analysis to reinforce the financial conclusions. The evaporation data indicate a significant water loss from Moroccan dams, with a total annual loss estimated at 909.46 million cubic meters. This total monthly evaporated volume for Morocco is illustrated in Fig. 2. Water loss is most pronounced during the summer months, peaking at 108.76 ×106m³ in July, followed by August and September. Figure 3 further details this by presenting the evaporation rates per month across Morocco. The study utilized the Stephen and Stewart model to evaluate these evaporation rates, a choice driven by its suitability for monthly applications and limited data availability. The data shows that water loss peaks during the summer, specifically in July at 108.76 ×106 m³, followed by August and September. These rates were evaluated using the Stephen and Stewart model, chosen for its suitability for monthly applications and an average absolute error of 1.21 mm/day. Table 1 ranks the five Moroccan dams with the highest annual evaporation values. Complementing this, Fig. 4 illustrates the volume of evaporated water for the top 18 dams in Morocco, a broader subset that includes those listed in Table 1. This broader subset highlights the reservoirs with the most significant water loss, dominated by the Al Wahda dam. Note: For technical accuracy, the values represent volumes in 103 m3 (thousands of cubic meters), resulting in a total annual evaporation magnitude of approximately 909 ×106 m3 across all monitored dams. The Al Wahda dam clearly dominates this ranking, with an annual evaporation of 183.88 ×106 m3. This high evaporation from Al Wahda can be attributed to several factors, including its large reservoir surface area, arid local climatic conditions, and the presence of aquatic vegetation that promotes evapotranspiration. A comprehensive overview of the total yearlyevaporated volume from each of the 58 dams studied is provided in Fig. 5, offering a complete picture of individual dam contributions to water loss. This provides a comprehensive overview of the individual contributions of all 58 studied dams to the total annual water loss of roughly 909.46 million cubic meters. The Al Massira and Oued El Makhazine dams occupy the second and third positions respectively, with annual evaporation values of 131.35 ×106 m3 and 76.86 ×106 m3. Although these values are significant, they are lower than that of the Al Wahda dam, suggesting the presence of mitigating factors for evaporation in these cases. The S.M. Ben Abdeellah and Idriss 1er dams show significantly lower annual evaporation compared to others in Table 1, with respective values of 47.10 m3 and 59.33 ×106 m3. These notable differences may be attributed to specific characteristics of these dams, such as reservoir depth, water level management, or local microclimatic conditions. Previous research in other regions has demonstrated the potential of FPV for water conservation: • In Spain, research carried out on a Floating Photovoltaic Cover System (FPCS) installed on an irrigation tank showed that the total coverage of the tank allowed an annual water saving of 5000 m³. This saving represents 25% of the reservoir’s storage capacity, confirming the effectiveness of this technology in improving water balances in arid and semi-arid areas12. • A study conducted in a semi-arid region demonstrated the effectiveness of floating solar panels in reducing evaporation, with an average decrease of 60% over a nine-month period14. • A study in Jordan showed that the use of FPV panels on water bodies could lead to a significant reduction in evaporation. Experimental results demonstrated that covering 30% of the water surface with floating panels saved 31.2% of water, while a 50% coverage led to a 54.5% water savings compared to an uncovered water body. These results highlight the potential of FPV systems to reduce water losses due to evaporation, offering a promising solution for water management in semi-arid regions19. Our estimates for Moroccan dams, with nearly one million cubic meters lost annually, highlight a substantial water conservation potential, aligned with the benefits observed in these international studies. However, a direct quantification of water savings resulting specifically from different FPV coverage rates for Moroccan dams is not detailed here. Morocco possesses substantial solar potential, benefiting from generous sunlight averaging 3000 hours per year and an estimated average daily solar radiation intensity of approximately 5.80 kWh/m²/day. This makes photovoltaic solar energy a sustainable and promising solution for the country. An overview of the distribution of solar radiation across Morocco is a valuable tool for identifying areas with high solar potential, which can inform the initial selection of potential sites for solar energy installations. It is crucial, however, to emphasize that this overview requires more detailed site-level assessments for an accurate and rigorous estimate. We used monthly horizontal irradiation data from 2020 from the PVgis platform for nine sampled dams. It is important to note that PVgis does not distinguish between day and night hours for temperature data, which may have limited the granularity of our subsequent efficiency estimation. The monthly declination angle (δ) plays a crucial role in determining the optimal tilt angle of solar panels, as it represents the angular position of the sun relative to the equator throughout the year. Table 2 provides monthly declination angles for Fès-Meknès, Morocco, offering valuable insights into the sun’s position throughout the year. As observed from Table 2, the declination angle varies considerably throughout the year, ranging from a maximum of 23.086° in June to a minimum of −23.050° in December. This variation is primarily due to the Earth’s tilt axis and its orbit around the sun. Our analyses show that annual solar production increases until it reaches an optimal tilt angle of 31 degrees, with an overall annual global radiation on a horizontal surface of 2361.16 kWh/m²/year, as depicted in Fig. 6. Analysis indicates that annual global radiation on a horizontal surface is 2361.16 kWh/m²/year, with production increasing until an optimal tilt angle of 31° is reached. Figure 7 visually represents the variation of solar elevation angles over the 12 months for the 9 samples. This information is useful for understanding the monthly distribution of solar radiation and for assessing the performance of solar panels throughout the year. Figure 8 illustrates the monthly evolution of radiation on the plane for different tilts. It demonstrates how the tilt angle significantly impacts the amount of solar radiation received by the panels, underscoring the importance of selecting the optimal tilt angle to maximize energy production. However, for reasons of structural stability and cost-effectiveness, an inclination of 11 degrees was selected for the energy production calculations. This visualization tracks solar elevation variations for representative dams (including Al Wahda and Al Massira). This demonstrates how tilt angles significantly impact monthly energy collection. The analysis of the surface area of the dams confirms the dominance of the five largest dams, as shown in Fig. 9. The total area of the 58 Moroccan dams monitored amounts to about 433 square kilometers. These surface results are strongly correlated with calculated evaporation results, reaffirming the importance of these five largest dams in the management of water and energy resources. The accurate calculation of these areas was made necessary by the lack of accessible and up-to-date data on the water bodies of the 58 dams. The total monitored surface area is approximately 433 km², determined through processing cartographic images. The results of this study indicate that covering approximately 40% of Morocco’s dam surfaces with FPV systems could generate sufficient energy to meet the country’s total electricity demand, which reached a total production of 42.38 TWh in 2023 according to the Ministry of Energy. This finding is illustrated in Fig. 10, which highlights the point at which energy production reaches 100% of national demand. The figure also compares the effects of different panel inclinations, specifically 11 degrees and 21 degrees, on energy generation. The comparison of tilt angles indicates that the difference in energy output between 11° and 21° is minimal, suggesting that lower tilt angles can be adopted without significantly affecting energy production while offering advantages in terms of stability and cost. Additionally, proximity to water enhances the cooling of PV panels, reducing their operating temperature and thereby improving overall efficiency. Projections suggest that covering 40% of the dam surfaces could meet Morocco’s total energy demand. Even with a low coverage rate, energy production from FPV systems remains considerable. With only 1% coverage, FPV installations could produce a significant amount of electricity. This is illustrated in Fig. 11, which shows the estimated annual production (in GWh) for 13 studied dams, highlighting the substantial contribution of even small-scale installations. To examine the versatility and impact of FPV systems across different generation targets, we also analyzed the coverage required for specific energy outputs. For instance, Fig. 12 presents the estimated coverage needed across at least 45 dams to collectively produce 100 MWh of energy annually. Similarly, Fig. 13 illustrates the percentage of coverage required for 11 dams to generate 1 GWh of energy per year. Together, these results underscore the efficiency and scalability of FPV systems as a robust renewable energy solution. They demonstrate that even modest coverage can significantly impact national electricity generation while meeting diverse energy targets. Even at 1% coverage, production levels reach a satisfactory level, contributing significantly to the national grid. This analysis highlights the feasibility of generating substantial power with minimal surface utilization. This focuses on high-potential large-area dams such as Al Wahda, Al Massira, and Oued Al Makhazin. The production analysis also showed a direct link between the efficiency of the solar panels, which are chosen primarily as polycrystalline cells with an efficiency of 16% for reasons of profitability and suitability for the large surfaces of the tanks, and the energy produced. Large-area dams, such as Al Wahda, Almassira, and Oued Al Makhazin, have a particularly high potential for energy production due to their favorable conditions. Regarding technical optimization, the study examined the effect of the tilt angle of the panels, finding that angles ranging from 11° to 31° gave comparable irradiation results. Figure 11 details the variation of the irradiation on the plane as a function of these angles. However, while the angle of inclination has a significant impact on irradiation, its effect on annual energy production is relatively negligible for small percentages of coverage (such as 1% of the total dam area). Conversely, for greater surface coverage (e.g., 40% of the dam area), the angle of inclination becomes a crucial factor in optimizing energy production and improving overall energy efficiency. In terms of cost analysis, Fig. 14 provides a comparative analysis of the costs of the two floating technologies C&T and Solaris. The analysis showed that the Solaris system has the best cost-effectiveness in terms of total cost of capital, making it more suitable for large-scale FPV projects. This economic trend is driven by the cooling effect of the water, which can enhance FPV production efficiency by up to 2% compared to ground-mounted systems. The results from Morocco’s 58 dams show that covering 40% of the total surface area could meet 100% of the country’s energy demand. This reflects a considerable potential for energy production. It highlights Morocco’s clear advantage regarding available surface area for FPV installations. As shown in Table 3, when we compare these projections with FPV projects around the world, Morocco’s potential looks very competitive. For example, a project in Greece has a capacity of 3861 MW and covers 10% of the area, producing about 5212.35 GWh annually. This shows significant success in deploying FPV on a large scale. Similarly, China’s Lake Chengxi project has a capacity of 320 MW and covers 1.5 km² (150 ha), generating 550 GWh annually. This indicates that FPV can work well even in smaller installations. In contrast, Singapore’s Tengeh Reservoir and Spain’s José María de Toro projects, while smaller in size, still make important contributions to their energy mixes, proving that FPV can succeed at different scales. FPV systems in Morocco could easily match or exceed the size of some of the biggest FPV projects worldwide. The vast surface area of 58 dams gives Morocco a clear advantage, providing great potential for renewable energy generation and helping the country meet its energy transition goals. In summary, the data suggests that Morocco’s FPV potential, backed by its large surface area and suitable conditions for floating solar technology, could play a vital role in meeting national energy needs and supporting global renewable energy targets. The comparative cost analysis revealed that the Solaris Synergy structure offers the best economic ratio in terms of total capital cost compared to the Ciel & Terre technology. Initial cost components include PV module costs adjusted to 0.22 USD/Wp and Engineering, Procurement, and Construction (EPC) costs at 0.31 USD/Wp. The financial projections suggest a Return on Investment (ROI) of less than 10 years. However, these projections must be interpreted with caution. Data regarding the maintenance and monitoring costs of FPV systems are poorly documented in current literature. Consequently, maintenance costs were estimated as a lump sum of approximately 10% of the capital expenditures over the lifespan of the panels. This lump-sum estimate makes the ROI projections speculative and insufficiently substantiated. To enhance the credibility of our financial conclusions and move beyond simplified assumptions, we have conducted a robust sensitivity analysis. This analysis systematically tests the impact of variations (e.g., ±10%) on the most critical parameters that influence the overall profitability of the project: Initial investment costs: Testing fluctuations in the costs of components such as PV Modules, the Balance of Plant (BOP), and EPC. Operation and maintenance (O&M) costs: Varying the generalized O&M estimate, which is currently 10% of capital expenditures, due to its inherent uncertainty. Electricity selling price: Testing fluctuations in the revenue stream, which significantly impacts long-term profitability. Technical parameters: Varying the efficiency (η) and the annual sum of solar irradiation (Yirr), factoring in the degradation rate of photovoltaic modules and the potential cooling effect. Macroeconomic factors: Including the influence of inflation and interest rates, which can alter the overall profitability of long-term investments. The sensitivity analysis confirms that while the technical potential is robust, as demonstrated by the negligible effect of minor tilt changes and the efficiency gains from cooling, the financial profitability is highly sensitive to the O&M costs and the electricity selling price. Fluctuations in O&M costs, due to the poor documentation in the literature, are identified as the largest driver of uncertainty in the ROI model. This analysis validates the conclusion that cost considerations must be tailored to each case to achieve more accurate and reliable results. The inclusion of this robust sensitivity analysis ensures that the financial projections are presented with the necessary rigor, affirming that asserting a rapid ROI based solely on simplified assumptions is insufficient. The tilt angle of FPV panels plays a crucial role in both maximizing energy production and reducing water evaporation. The cooling effect of water is one of the key advantages of FPV systems, as it significantly improves panel efficiency, reducing heat-induced performance losses commonly observed in traditional land-based solar systems. In our study, we observed that the tilt angle significantly affects irradiation and energy production. The optimal tilt angle for FPV panels varies depending on the geographical location and the specific characteristics of the site. For Morocco, we found that tilt angles ranging from 11° to 31° yielded comparable irradiation values (see Fig. 11), with an 11° tilt angle being the most cost-effective while still providing substantial energy output. This angle maximizes solar exposure, particularly in regions with high solar radiation throughout the year. For larger-scale installations, such as 40% coverage, the tilt angle becomes more critical in optimizing solar energy capture. Panels tilted at optimal angles maximize the amount of solar radiation received, leading to increased energy output. In contrast, at smaller coverage (e.g., 1% of the surface area), the effect of tilt is negligible, as the total energy produced is too small to be significantly affected by slight variations in the angle of the panels. In addition to its effect on energy production, the tilt angle of FPV panels also influences the cooling effect on the water beneath the panels, which reduces water evaporation. The cooling effect is particularly important in regions where water scarcity is a major concern. By shading the water surface, FPV systems help to maintain lower water temperatures, reducing the evaporation rate. As the tilt angle increases, the shading effect on the water surface decreases, allowing more solar radiation to reach the water, which may increase the evaporation rate. Our study shows that an optimal tilt angle, such as 11°, achieves a balance between energy production and water conservation. While higher tilt angles may slightly increase energy yield, they reduce the shading effect on water and may increase evaporation. In contrast, lower tilt angles enhance shading and help limit water loss. Additionally, proximity to water improves PV efficiency through natural cooling, making FPV systems particularly suitable for water-scarce regions. This study, which primarily focused on surface potential and evaporation rates, acknowledges a significant gap in hydrological design data. Specifically: Hydrological Risks: An in-depth analysis of hydrological risks, including depth variations and drought conditions, is imperative for a comprehensive evaluation of FPV systems. Depth Data: The study could not document the average and minimum depths of the studied dams. This data would be essential for understanding the impact of water level fluctuations on the stability and performance of FPV systems. Drought Impact: Additionally, the study did not model the impact of prolonged droughts (a known challenge in Morocco) on the performance and safety of FPV systems. Such an analysis is critical to ensure that anchoring systems are designed to withstand significant fluctuations in water levels, ensuring the long-term resilience of the FPV installations. These data are crucial for designing robust anchoring systems and ensuring the safety and performance of FPV installations, especially when dealing with hydrological risks such as droughts and fluctuations in water levels. FPV systems, like other solar technologies, face challenges with inconsistent energy output, especially due to cloud cover and seasonal changes in solar energy availability. In Morocco, some regions have high cloud coverage during certain seasons, leading to notable variations in energy output. To address this issue, energy storage options like pumped hydro storage and green hydrogen are essential for stabilizing energy supply. Pumped hydro storage allows for storing excess energy generated during peak sunlight hours, which can then be released during periods of low sunlight, ensuring a steady energy supply. Green hydrogen offers a novel way to store surplus energy as hydrogen, which can be used in various sectors, including industry and transportation. Moreover, integrating smart grid technologies is vital for managing these variations and maintaining grid stability. Smart grids allow for real-time energy management and demand-response systems, enabling more efficient energy distribution and balancing supply with demand. These systems will be key to effectively integrating FPV systems into Morocco’s national grid and ensuring the long-term sustainability of renewable energy sources. In the event of a platform failure, safety protocols are in place to ensure the stability of the FPV system. These protocols include the use of redundant systems that allow for emergency shutdowns in case of unexpected events. Additionally, the floating platforms comply with international safety standards such as IEC, DNV, and ISO, ensuring that they can withstand harsh weather conditions and prevent large-scale disruptions. This guarantees that the FPV systems are both safe and resilient, capable of operating under challenging environmental conditions. In terms of future perspectives and research, an in-depth assessment is needed to measure the gains in water resources resulting from FPV installations, considering different coverage configurations. It is also essential to address gaps in data regarding the efficiency of Moroccan dams to refine the understanding of their energy potential. Further research could also validate the Stephen and Stewart evaporation model used with in situ data specific to Moroccan dams, or explore more sophisticated models should additional data become available. Finally, dedicated studies on the optimal integration of FPV systems with storage solutions, such as green hydrogen and pumped storage, are necessary to maximize their contribution to Morocco’s energy security and energy transition. In conclusion, this study delved into various aspects of FPV systems and revealed their substantial potential for power generation and water conservation in Morocco. Our findings highlight possible solutions to the storage challenge, such as pumped hydro-storage systems and promising green hydrogen technology. Addressing Morocco’s significant evaporation losses, this study quantifies nearly 1 billion (909.4 × 106) cubic meters lost annually due to evaporation. The total water surface of the monitored dams in Morocco is approximately 433 km², with the optimal tilt angle for the floating platforms ranging from 11° to 21°, based on the country’s geographical location. In terms of energy generation, covering only 40% of the dams could meet the entire energy demand, although this may change depending on varying storage system efficiencies. The cost per kWh significantly decreased when considering the additional efficiency from the cooling effect of water. Despite the substantial upfront investment, the study suggests a return on investment of less than 10 years, factoring in maintenance costs. However, cost considerations should be tailored to each specific case to obtain precise and accurate results. Although this study explored various aspects of FPV systems, it acknowledges its non-exhaustive nature and emphasizes the need for continued research to fully understand the impact of FPV systems on Morocco’s energy and water management strategies. For Morocco to fully leverage the massive FPV potential and address the intermittency inherent in solar power production, large-scale storage solutions will be crucial. The study identifies pumped storage systems (potentially linked to existing dam infrastructures) and green hydrogen technology as pathways to address this storage challenge. It is important to emphasize that this study lays the groundwork for specific research into these solutions, which were not the primary focus of this study. This study adopted a rigorous and multi-layered methodology to assess the potential of FPV systems on Moroccan dams. While drawing upon established models and techniques, the originality and major contribution of this research lie in the exhaustive application and contextualization of these approaches to the scale of Morocco’s 58 dams. This approach enabled the generation of unprecedented data and analyses, crucial for the country’s energy and water planning. The key steps of the methodology include estimating evaporation rates, calculating solar irradiation, precisely determining the surface area of the dam water bodies, evaluating electrical energy production, and conducting a detailed cost analysis. The FPV system consists of several key components, including solar panels, inverters, and transformers, as shown in Fig. 15. The solar panels are mounted on floating platforms that rest on the surface of the dams. Underwater cabling connects the floating panels to the onshore components, such as inverters and transformers, which convert the generated direct current into alternating current suitable for integration into the electrical grid. Installing the inverters and transformers onshore minimizes the risk of electrical faults due to water exposure, simplifies maintenance, and reduces system complexity compared to placing these components on floating platforms. This configuration adheres to industry standards for safety and operational efficiency, ensuring reliable performance in aquatic environments. This diagram illustrates the key components and configuration of the FPV system. Two FPV structural models, shown in Fig. 16, were selected for this study based on their cost-effectiveness, adaptability to Moroccan dam conditions, and compliance with international standards. The first model, developed by Ciel & Terre (C&T), was chosen for its proven performance in large-scale installations and its ability to adapt to various water depths and climatic conditions. The second model, developed by Solaris Synergy, was selected for its optimized design, which offers a favorable balance between capital cost and system performance. Both models comply with international standards such as IEC, DNV, and ISO, ensuring they meet the required safety, structural integrity, and performance criteria for long-term operation in harsh environmental conditions. a Ciel & Terre (C&T) technology36 and (b) Solaris Synergy technology37. Solaris was found to have the best economic ratio for total capital cost. To estimate evaporation rates, available data sources and various existing models were analyzed. The Stephen and Stewart model, represented by Eq. (1), was specifically applied26. This model was chosen due to its suitability for monthly applications and, critically, due to limited data availability for more complex models27. It is recognized for its average absolute error of 1.21 mm/day on small reservoirs. Where: e: Evaporation (mm/day) Qs: Solar radiation (W/m²) Ta: Average Air Temperature (°F) For data acquisition, temperature information was obtained from the PVGIS platform. For this study, monthly average temperatures were utilized to maintain methodological consistency with the Stephen and Stewart model, which is specifically optimized for monthly applications. Samples were collected from nine representative dams (ALWAHDA, AL MASSIRA, ABDELMOUMENE, MANSOUR DAHBI, NEUF AVRIL, NAKHLA, SMIR, HASSAN 2, MOULAY YOUSSEF) with total average temperatures ranging from 16 °C to 21 °C28. Furthermore, the average daily value of solar radiation intensity in Morocco was estimated at approximately 5.80 kWh/m²/day. This value was converted into power by dividing it by the daylight hours of each month29. This systematic application of the model to all Moroccan dams constitutes an advance for quantifying water losses specific to the national context, essential for evaluating the impact of FPV systems on water resource conservation in Morocco. For irradiation data, we accessed monthly horizontal irradiance on a horizontal plane for the year 2020 from the PVGIS website. We used data from the nine previously mentioned dams along with associated temperature readings. From the calculated horizontal irradiance, we derived the inclined plane irradiance using Eq. (2): Where: Imodule: The irradiation on the inclined surface (kWh/m²). Ihorizon: The horizontal irradiation (kWh/m²) on a flat surface. α : The solar zenith angle, which represents the angle between the sun and the vertical. It depends on the latitude, time of year, and time of day. β : The tilt angle of the solar panels (degrees). To calculate the solar zenith angle (α), we used the following formula: Where: ϕ is the latitude of the location (in degrees), δ is the declination angle, which is calculated using the formula: Where: d is the day of the year (ranging from 1 to 365). For the choice of days of the months, we used the average days of each month suggested by Klein, as shown in Table 430. Subsequently, an annual average of the inclined plane irradiation was obtained for each inclination studied by averaging the monthly values. These calculations allowed for the customization of irradiation data for the Moroccan geographical context, ensuring precise results for optimizing the tilt angle of floating solar panels. To estimate the water surface areas of the 58 dams in Morocco, a specific method based on color image processing was employed due to the lack of up-to-date official data. Initially, cartographic images of the dams were collected using Viking software and Bing Aerial, with Viking software enabling an accurate representation of the actual water surface areas. A simple image processing technique was then applied to delimit the area outside the dam, minimizing potential errors in the estimation. The Color Summarizer program, known for its high precision, was used to calculate the exact percentage of water surface in each dam31. Based on the resolution of the satellite imagery and the accuracy of the color classification algorithm, the margin of error for this method is approximately ±5%. To ensure the accuracy of the surface area estimates, the results were verified by comparing them with historical official dam data and documents from the Moroccan Ministry of Equipment and Water. This verification confirmed that the estimated water surface areas are generally reliable. However, it should be noted that these results are relatively constrained by recent drought conditions in Morocco, which have led to reduced water levels in many dams over the past few years. These estimates provide a sound basis for the subsequent analysis of FPV system feasibility, while acknowledging the temporal variability in water availability. Figure 17 illustrates the application of this methodology using the Al Mansour Eddahbi Dam as a representative example. a Step 1: Initial image surface of 174.54 km². b Step 2: Cutting to delimit the dam. c Step 3: Color processing and cluster partitioning using the Color Summarizer program. The water surface (({S}_{{water}})) was calculated as follows: Where: S_water: the water surface area of the reservoir, typically measured in square meters (m²) or square kilometers (km²). This is the area of the water body covered by FPV systems. S_image: the total surface area of the image or the satellite-derived image of the entire reservoir. This is the total area (including land and water) captured in the image, typically in m² or km². % of the water color: the percentage of the image that is covered by water, based on color analysis. The color of water in an image can be identified using image processing techniques that classify pixels as water based on their color or spectral properties. This percentage is typically expressed as a percentage (%) and represents how much of the image is covered by water versus land. The primary outcome of utilizing solar panels is the generation of electrical energy, which is well established. However, in the case of FPV systems, based on previous studies in basins, there is a notable improvement in the panel efficiency, as illustrated in Table 5. Furthermore, the quantitative results of electrical energy production are influenced by various factors (inclination angle, location, panel type, temperature, etc.), with irradiation being a direct determinant. Drawing from previous research32, the average annual electrical energy production from FPV implementation, under approximate conditions and utilizing less than 2% of the surface area of large dams in Morocco, will reach a satisfactory level of 2064.6 GWh. This study examines the annual electricity production of different types of crystalline solar panels (Table 6) at varying inclination angles. The following model was employed to estimate the corresponding annual electricity production (6): Where: EFPV is the annual electricity production (MWh/year). AFPV is the surface area covered by FPV panels (m²). PR is the system performance ratio (%). η is the solar panel efficiency (%). Yirr is the annual sum of solar irradiation energy at a given inclination angle, averaged for the reservoir surface (kWh/m²). For reasons of cost-effectiveness and suitability for large reservoir areas, polycrystalline cells with an efficiency of 16% were prioritized. Cost-benefit analysis is crucial for evaluating PV systems from an investment perspective. For FPV installations, the investment cost encompasses the price of PV modules and their accessories, the cost of the supporting structure, and maintenance expenses (including installation). In this study, the assessment approach is based on the average lifespan of the panels, adjusted for the period required to recover initial stable losses and maintenance costs. The choice of structure and solar panel technology significantly influences the total initial investment. The costs of solar equipment were determined based on the work of Wang and Barnett33. PV module costs were adjusted to 0.22 USD/Wp. The “balance of plant” (BOP) costs, including transformers, wiring, switching and control equipment, protective equipment, etc., are presented in Table 7. In this study, two main FPV structures: Ciel & Terre and Solaris Synergy (see Fig. 16), are compared, as shown in Table 8. Differences in manufacturing and logistical costs for the floaters are observed between the two structure concepts, with Solaris Synergy generally being less complex and potentially easier to manufacture. The maintenance and monitoring costs of FPV systems, although poorly documented in current literature, were estimated at approximately 10% of the capital expenditures over the lifespan of the panels34. The datasets generated and analyzed during the current study are not publicly available because they consist of strategic technical estimations for 58 national dams derived from satellite imagery and theoretical modeling, which require further validation by real operational data. They are, however, available from the corresponding author on reasonable request. The code used for the analysis in this study is not publicly available as it is part of a specific research framework developed for this national assessment; it is available from the corresponding author on reasonable request. 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Article Google Scholar Download references This publication is a result of the research project ‘Innovative Floating Photovoltaic Systems to Combat Climate Change and to Decrease the Cost of PV Energy, ’ funded by the Arab-German Young Academy of Sciences and Humanities (AGYA). AGYA drew on support from the German Federal Ministry of Education and Research (BMBF; grant no. 01DL20003). The authors remain solely responsible for the content provided in this publication, which does not reflect the positions of the AGYA or any of its funding partners. Laboratoire des Sciences Appliquées et Technologies Innovantes, ENSA, USMBA, Fès, Maroc Abdelilah Mouhaya, Abdelaziz El Ghzizal & Saad Motahhir Engineering Laboratory for Intelligent Technologies and Transformation, EST, Abdelmalek Essaadi University, Tetouan, Morocco Aboubakr El Hammoumi Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar Abdelilah MOUHAYA: Writing – review and editing, Writing – original draft, Visualization, Methodology, Investigation, Conceptualization. Aboubakr EL HAMMOUMI: Writing – review and editing, Writing – original draft, Visualization, Methodology, Investigation, Conceptualization. Abdelaziz EL GHZIZAL: Writing – review and editing, Supervision, Methodology, Investigation, Conceptualization. Saad MOTAHHIR: Writing – review and editing, Supervision, Methodology, Investigation, Funding acquisition, Conceptualization. Correspondence to Abdelilah Mouhaya. The authors declare no competing interests. Publisher’s note Springer Nature remains neutral with regard to jurisdictional claims in published maps and institutional affiliations. Open Access This article is licensed under a Creative Commons Attribution-NonCommercial-NoDerivatives 4.0 International License, which permits any non-commercial use, sharing, distribution and reproduction in any medium or format, as long as you give appropriate credit to the original author(s) and the source, provide a link to the Creative Commons licence, and indicate if you modified the licensed material. You do not have permission under this licence to share adapted material derived from this article or parts of it. The images or other third party material in this article are included in the article’s Creative Commons licence, unless indicated otherwise in a credit line to the material. 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Grand View Research, Inc. Global market projected to expand at a CAGR of 6.4% from 2026 to 2033 as governments, utilities, and enterprises accelerate investments in resilient and low-carbon energy systems. SAN FRANCISCO, June 18, 2026 /PRNewswire/ — The global distributed energy generation market is entering a new phase of expansion as countries worldwide intensify efforts to modernize power infrastructure, strengthen grid resilience, and accelerate the transition toward cleaner energy systems. According to a recent industry analysis by Grand View Research, the global distributed energy generation marketwas valued at USD 538.2 billion in 2025 and is expected to grow from USD 572.1 billion in 2026 to USD 884.8 billion by 2033, registering a compound annual growth rate (CAGR) of 6.4% during the forecast period. Distributed energy generation (DEG) refers to decentralized power production technologies located near the point of consumption, including solar photovoltaic systems, wind turbines, fuel cells, combined heat and power systems, microturbines, and other localized energy assets. These systems are transforming how electricity is generated, distributed, and consumed by reducing dependence on centralized power plants and improving energy reliability. As energy security becomes a strategic priority for governments and businesses alike, distributed generation technologies are emerging as critical components of next-generation energy infrastructure. Rising electricity demand, increasing renewable energy deployment, and growing concerns regarding grid resilience are creating favorable conditions for sustained market growth. Industry analysts note that the shift toward decentralized power systems is being reinforced by supportive government policies, advancements in energy storage technologies, and growing investments in smart grid infrastructure. Organizations across residential, commercial, and industrial sectors are increasingly adopting distributed generation solutions to reduce operating costs, improve sustainability performance, and ensure uninterrupted access to electricity. Solar Photovoltaic Technology Maintains Market Leadership Among all technology segments, solar photovoltaic (PV) systems continue to dominate the global distributed energy generation landscape. The solar PV segment accounted for 61.3% of total market revenue in 2025, making it the largest technology category within the industry. Several factors are contributing to solar PV’s strong position, including declining module prices, expanding rooftop solar installations, favorable regulatory incentives, and increasing integration with battery storage systems. Solar photovoltaic technology is also projected to be the fastest-growing technology segment through 2033, with an anticipated CAGR of 8.3%. The growing availability of high-efficiency panels, smart inverters, and digital energy management platforms is further enhancing the economic viability of distributed solar projects. Commercial facilities, manufacturing plants, educational institutions, healthcare centers, and residential consumers are increasingly investing in onsite solar generation to reduce electricity costs and achieve sustainability objectives. Get free PDF Sample for more Industry Insights on this Report Asia Pacific Emerges as the Largest Regional Market Geographically, Asia Pacific remains the largest market for distributed energy generation, accounting for 34.9% of global revenue in 2025. Rapid urbanization, industrial development, population growth, and government-backed renewable energy initiatives continue to drive adoption throughout the region. Countries across Asia Pacific are actively expanding rooftop solar programs, distributed wind projects, hybrid microgrids, and battery storage installations. The region’s extensive manufacturing ecosystem for solar panels, inverters, and energy storage technologies has also contributed to lower deployment costs and broader market accessibility. China continues to play a particularly significant role in regional growth. Large-scale distributed solar deployment initiatives, strong domestic manufacturing capabilities, and long-term renewable energy targets have positioned the country as a key contributor to global market expansion. Latin America Poised for Accelerated Growth While Asia Pacific currently leads the market, Latin America is expected to emerge as the fastest-growing regional market during the forecast period. The region is projected to achieve a CAGR of 14.5% through 2033, supported by expanding electricity demand, favorable distributed solar policies, and increasing investments in decentralized energy infrastructure. Countries throughout Latin America are implementing net metering programs and distributed generation incentives designed to improve energy accessibility while reducing pressure on centralized transmission networks. As solar installation costs continue to decline, both residential and commercial adoption rates are expected to accelerate significantly. Grid Modernization and Energy Storage Reshape Industry Dynamics A major trend influencing market development is the integration of distributed energy resources with advanced digital technologies. Utilities and energy providers are increasingly deploying smart grid systems, microgrids, energy management platforms, and virtual power plant models to optimize energy production and consumption. Energy storage technologies are also playing a pivotal role in enabling greater penetration of distributed renewable generation. Advances in lithium-ion battery systems and intelligent storage management solutions are helping address intermittency challenges associated with renewable energy resources. The combination of distributed generation and energy storage is creating new opportunities for consumers and businesses to become active participants in energy markets while enhancing overall grid stability. Corporate Sustainability Goals Drive Commercial Adoption Beyond policy support and technological innovation, growing corporate sustainability commitments are becoming a major catalyst for market expansion. Businesses across multiple industries are adopting distributed generation solutions to reduce carbon emissions, improve energy resilience, and meet environmental, social, and governance (ESG) objectives. Data centers, manufacturing facilities, healthcare institutions, and commercial campuses are increasingly investing in onsite renewable generation and storage systems to mitigate energy risks and improve operational efficiency. This trend is expected to remain a key growth driver throughout the forecast period. Get customized research report as per your requirements Competitive Landscape The distributed energy generation market is characterized by active innovation and strategic investment from leading global energy and technology companies. Market participants are focusing on expanding renewable energy portfolios, strengthening energy storage capabilities, and developing intelligent grid management solutions. Key companies operating within the market include Tesla, Siemens AG, Schneider Electric SE, General Electric, ABB Ltd., Enel Green Power, SMA Solar Technology AG, Bloom Energy Corporation, NextEra Energy, Inc., and Honeywell International Inc. These organizations continue to invest in advanced distributed energy technologies, digital monitoring platforms, microgrids, and virtual power plant capabilities to address evolving customer requirements and support the global transition toward decentralized energy systems. Looking Ahead As nations pursue ambitious decarbonization targets and energy resilience strategies, distributed energy generation is expected to become an increasingly important pillar of the global energy ecosystem. Continued advancements in renewable technologies, battery storage systems, and digital energy management platforms are likely to accelerate adoption across all major regions. With market value projected to reach USD 884.8 billion by 2033, distributed energy generation is positioned to play a critical role in enabling a more sustainable, reliable, and flexible energy future. To learn more about growth opportunities in the Distributed Energy Generation Market, access the full report from Grand View Research About Grand View Research Grand View Research, U.S.-based market research and consulting company, provides syndicated as well as customized research reports and consulting services. Registered in California and headquartered in San Francisco, the company comprises over 425 analysts and consultants, adding more than 1200 market research reports to its vast database each year. These reports offer in-depth analysis on 46 industries across 25 major countries worldwide. With the help of an interactive market intelligence platform, Grand View Research Helps Fortune 500 companies and renowned academic institutes understand the global and regional business environment and gauge the opportunities that lie ahead. Browse Investment Insights by Grand View Research – a dedicated, scalable fundamental research platform designed to function as a seamless extension of investment teams across the buy-side and sell-side ecosystem. Contact: Michelle Thoras Corporate Sales Specialist, USA Grand View Research, Inc. Phone: 1-415-349-0058 Toll Free: 1-888-202-9519 Email: sales@grandviewresearch.com Web: https://www.grandviewresearch.com Follow Us: LinkedIn | Twitter Blog – https://globalindustryherald.com/ View original content to download multimedia:https://www.prnewswire.co.uk/news-releases/distributed-energy-generation-market-to-reach-usd-884-8-billion-by-2033–driven-by-renewable-energy-adoption-grid-modernization-and-decentralized-power-infrastructure-302803378.html Originally published on the BLOX Digital Content Exchange. Your browser is out of date and potentially vulnerable to security risks. We recommend switching to one of the following browsers: This site is for CNHI, LLC employees only. Please enter your cnhinews.com credentials to access this site. If you have any questions please contact help@cnhionline.com
PLOVER, Wis. (WSAW) – Someone cut through a fence at the end of May, broke into equipment trailers and got away with about $95,000 in Milwaukee-brand tools from a solar farm. Sheriff Mike Lucas said investigators are working to determine whether the solar farm was specifically targeted. “I don’t know if this was targeted in regards to the solar farm. We don’t know. We’re looking in regards to, you know, somebody had to know that there was that much equipment out there. So we’re working on that angle also,” Lucas said. The 130 items missing include multiple wire cutters, grease guns, about 80 batteries, more than 40 half-inch impact guns and a couple of small generators. The theft happened near Monroe Avenue between Prairie and Forest drives off of Highway 54. Investigators collected evidence at the scene, including tire impressions, and have serial numbers for all the tools. Lucas warned buyers that if they purchase stolen tools — often sold online or trafficked out of state — the items can be seized and they could lose their money or even face charges if they knowingly buy stolen property. “A good idea is to maybe write down that license plate of the person that you got that from, because if by chance we come and knocking on your door and we take that equipment back, you actually have something that maybe can assist in recouping some of your money,” Lucas said. He is asking the public to watch for bulk Milwaukee tools being sold “too good to be true.” Lucas said thefts of this scale raise costs that ultimately get passed on to consumers through higher prices and insurance premiums. Anyone with information about this or any crime can contact Portage County Crime Stoppers through the P3 app, call the number provided or submit a tip online. Tipsters can remain anonymous and may be eligible for a cash reward. Click here to download the WSAW news app or WSAW First Alert weather app. Click here to submit a news tip or story idea. Copyright 2026 WSAW. All rights reserved.
Crisil expects domestically manufactured solar cells to account for half of India’s total demand this fiscal 2026-27, up from about one-fourth last fiscal. This strong uptick will be driven by the government’s push to reduce dependence on imports, supported by a strong ramp-up in solar cell manufacturing capacity. However, such large capacity additions are likely to put pressure on capacity utilisation and realisations, potentially extending payback periods for cell manufacturers. The estimates are based on Crisil’s assessment of solar cell manufacturing capacity expansion plans announced by domestic module and cell manufacturers. Following the implementation of the Approved List of Models and Manufacturers (ALMM) from April 1, 2024, the Ministry of New and Renewable Energy (MNRE) extended localization requirements upstream through the Approved List of Cell Manufacturers (ALCM), aiming to reduce dependence on imported cells in the solar PV supply chain. Applicable from June 2026, the ALCM is mandatory for utility-scale projects with bid submission dates after Aug. 31, 2025, and for net-metering and open-access projects commissioned after June 1, 2026. Residential rooftop solar installations under the PM Surya Ghar: Muft Bijli Yojana are exempt from the requirement until March 31, 2027. “The ALCM will sharply reset India’s solar cell supply mix. Domestic supply will gain share and meet around half of the 60-65 GW demand this fiscal, with imports making up for the rest,” said Manish Gupta, Deputy Chief Ratings Officer, Crisil Ratings. “The shift will be led by demand for indigenous cells from newer utility-scale bids, net-metering and open-access projects, and government-backed schemes such as Kisan Urja Suraksha Evam Utthaan Mahabhiyan, or KUSUM. Meanwhile, imports will mainly be for the pipeline of unexecuted utility-scale projects with bid submissions prior to the August 31, 2025 cut-off. As the earlier project pipeline winds down, import dependence should fall materially starting next fiscal.” With rising demand and anticipated reduction in imports, several manufacturers are undertaking capital expenditure to set up or expand solar cell manufacturing capacities. Crisil expects India’s cumulative solar cell capacity to nearly double to 60 GW by the end of this fiscal, with further additions likely over the next fiscal. This could challenge the returns on new solar cell manufacturing capacities. Says Ankit Hakhu, Director, Crisil Ratings, “The surge in solar cell capacity will redraw project economics. Capacities commissioned by the end of this fiscal could see payback periods stretch by 1-2 years, compared with the 4-5 years it took the early movers integrating backward to solar cell manufacturing. These early movers benefited from higher premiums and 50-60% capacity utilisation after stabilisation—advantages that are likely to narrow as fresh capacity comes on stream.” The payback periods are crucial given the rapid evolution of technology in the sector, which can shorten the economic life of assets, particularly where reliance on imported raw materials adds to margin volatility. Manufacturers pursuing deeper backward integration into ingot and wafer manufacturing—currently almost entirely imported—are likely to see better returns through higher realisations following the government’s notification on the likely applicability of ALMM III (ALMM for solar ingots and wafers) from June 2028 onwards. A key monitorable is the risk of weaker solar module demand arising from delays in power purchase agreement signings. Moreover, the MNRE has also set up an expert committee to assess ALCM exemption requests for net-metering and open-access projects with installed but uncommissioned modules, or where developers have taken substantive steps toward project implementation. Any material exemption affecting demand for indigenous cells will bear watching. Comments Please login to comment The June issue of pv magazine Global is out now! Available in print and digital – get your copy today! Thursday, July 9, 2026 11:00 am – 12:30 pm CEST, Berlin, Paris, Madrid Thursday, June 18, 2026 2:00 pm – 3:00 pm CEST, Berlin, Paris, Madrid Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects. April 01 – August 31, 2026 pv magazine Insight will be held on October 30, at The Battery Show India Expo 2025 and moderated by pv magazine’s Uma Gupta and Mark Hutchins.
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Pradershika Sharma is a tech deals writer for Lifehacker.
She has a Master’s degree in English Literature, a B.Ed., and a TESOL certification. She has been writing professionally since 2018, creating product reviews, affiliate articles, and search ads for global clients while working with Rubix Agency and Cognizant. Previously, she spent a year teaching English at the junior high level.
An avid reader since childhood, Pradershika’s idea of extreme sports is staying up to read “just one more chapter.” She lives in India. Right now, the Solix F3800 portable power station bundle is down to $1,999.98 from its usual $3,999 price. According to price trackers, that’s the lowest price this package has reached so far. We’re also keeping track of other notable discounts and buying advice across a wide range of categories for this year’s Prime Day sales event. With a 3,840Wh battery and up to 6,000W of output, the F3800 is built for more than keeping phones and laptops charged during an outage. Most portable power stations are limited to standard 120V outlets, which covers TVs, computers, lights, and small appliances, but the F3800 also supports 240V output, allowing it to power larger appliances that many competing models simply can’t handle. That includes electric dryers, ovens, certain air-conditioning systems and EVs, and an RV through its dedicated 30-amp outlet. Anker also designed the system with expansion in mind. You can add up to six expansion batteries, increasing total capacity to 26.88kWh. The included 400W solar panel also adds another layer of flexibility—if you’re using the system for camping, RV travel, or extended outages, you can replenish some of that capacity without relying entirely on the electrical grid. The panel uses high-efficiency monocrystalline cells, offers adjustable stand angles to help capture more sunlight throughout the day, and carries an IP67 weather-resistance rating for outdoor use. The biggest drawback here is portability. Despite the wheels, the Solix F3800 weighs more than 130 pounds, so this isn’t something you’ll casually carry from place to place. It’s better thought of as a movable backup-power system than a grab-and-go battery pack. It’s also still a significant investment, even at half off.
Norwegian-headquartered renewables developer Scatec has started constructing the 120 MW Sidi Bouzid II solar plant in Tunisia after reaching financial close. Total capital expenditure for the project is estimated at €96 million ($110.1 million) and is being financed by a combination of non-recourse debt and equity. Senior lenders for the project are the European Bank of Reconstruction and Development and European Investment Bank, with additional grant funding from the EU Neighbourhood Investment Platform and guarantees from the European Fund for Sustainable Development Plus. Scatec signed a power purchase agreement (PPA) for the project in December 2024 following a government tender. The company is developing the Sidi Bouzid II project alongside Aeolus SAS, part of the Japanese conglomerate Toyota Tsusho Group. The two parties both own 50% of the project. The site is expected to reach commercial operations during the second half of 2027, with Scatec set to provide engineering, procurement and construction (EPC), asset management and operations and maintenance services with an EPC scope of approximately 75% of capital expenditure. Terje Pilskog, CEO of Scatec, said the Sidi Bouzid II project is the company’s third under construction in Tunisia. Scatec and Aeolus switched on the 60 MW Sidi Bouzid project earlier this year. In January, Scatec announced it signed a 25-year PPA with Tunisian state utility STEG for the 120 MW Tataouine solar power plant. Tunisia has over 2.4 GW of operational solar, according to figures available in the Africa Solar Industry Association’s (AFSIA) project database, including 357 MW of utility-scale solar. Last December, the country switched on a 120 MW solar project, its first above 100 MW. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: [email protected]. Comments Please login to comment The June issue of pv magazine Global is out now! Available in print and digital – get your copy today! Thursday, July 9, 2026 11:00 am – 12:30 pm CEST, Berlin, Paris, Madrid Thursday, June 18, 2026 2:00 pm – 3:00 pm CEST, Berlin, Paris, Madrid Be part of the high-level European conference on solar and energy storage, exploring bankable BESS projects, warranties, and energy management for residential and C&I sectors Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects. April 01 – August 31, 2026 A two-day conference in Austin, Texas, bringing together leaders in US solar manufacturing, equipment specification, and factory execution. Saudi Arabia is accelerating its clean energy transition—join the SunRise Arabia Clean Energy Conference 2026 in Riyadh to explore how solar PV and energy storage are powering its digital economy. Showcase your brand across all our platforms: from 13 websites in 7 languages to our magazines, daily newsletters, industry events and more. Reach your audience the right way! We are participating in Intersolar 2026 again this year! Visit us at our Booth Hall 2 A2.250 to discuss the latest trends within the photovoltaic industry with the pv magazine team. June 23-25, 2026 | MUNICH, GERMANY
Bolivia’s state power company Ende has selected a firm to advance the US$110mn, 120MW Chichas solar project in Tupiza, Potosi department. Bolpegas won the pre-investment contract and will have 150 days to complete the work. The tender was launched in April. Tasks include a technical design study, including basic engineering design, as well as economic, financial and market studies, and environmental and social assessments. This week, President Rodrigo Paz authorized the construction of the 40MW Contorno Bajo I photovoltaic project in Viacha after lawmakers approved a 34mn-euro (US$39mn) loan from German development bank KfW in April for the plant. Ende’s solar development pipeline includes the 30MW Occidente project. [insight#260217538] (The original version of this content was written in English) Subscribe to the leading business intelligence platform in Latin America with different tools for Providers, Contractors, Operators, Government, Legal, Financial and Insurance industries. The project would span the departments of Santa Cruz and Chuquisaca. There are ten lots that will be moved from Puerto Jennefer to where the Warnes II project is installed. Subscribe to Latin America’s most trusted business intelligence platform. Get critical information about thousands of Electric Power projects in Latin America: what stages they’re in, capex, related companies, contacts and more.
One of the outgrowths of the pending sunset of the Federal Investment Tax Credit and a slowdown in new large-scale solar projects entering service is that existing assets, both in service and under construction, may become more valuable. Buyers are active and owners are putting together larger and more diverse portfolios of PV projects. A recent study by the PV Performance and Analytics Modeling Collaborative (PVMAC) at Sandia National Laboratories reports that the rise of large, complex solar portfolios is causing fragmentation in operational data that could threaten output performance and financial returns. The problem, the authors assert, is that many stakeholders, which may have limited industry experience, are not fully aware of the importance of PV operations software on plant performance. At its core, the problem is the lack of standards for reporting, the study says, particularly in key performance indicators (KPI) metrics. “The [solar] industry lacks clear and consistent understanding of PV operations software, and many stakeholders are not fully aware of the importance of these tools for improving operational performance,” the report states. “This makes it difficult to assess capabilities, compare approaches, and make informed decisions.” The PVMAC solicited the input of 24 providers of operations and maintenance (O&M) software providers to assess the capabilities, integration practices and operational functionality of their commercial systems representing more than 1.1 TW of solar assets across over 115,000 sites. The responses indicated that while 70% of platforms offer public application programming interfaces (APIs), 30% still place restrictions and costs on data export. The report also found that only 17% of providers publicly document their KPI performance methodologies and only about half claim KPI reproducibility, making it difficult for operators to consistently evaluate performance across assets and platforms. According to Texas-based enSights, a provider of O&M intelligence and energy business management software that participated in the research, challenges compounded by different data access points across manufacturers, distributed energy resource asset age and operational platforms. “The data accessibility issue and array of different performance KPI definitions are only compounding the data fragmentation challenge, at a time when operators are under increasing pressure to optimize portfolio performance and returns,” said Alon Mashkovich, co-founder and CEO of enSights. “A fragmented data landscape that makes it increasingly difficult for operators to gain a clear understanding of portfolio performance, ultimately limiting their ability to maximize returns and realize the full value of their assets.” Mashkovich added that by removing these barriers, software providers will be able to enable operators to obtain a clearer view of their portfolios that will enable better decisions, stronger performance and greater confidence in the data that drives them. The Sandia report offers the following takeaways on O&M software characteristics and their potential pitfalls: Mashkovich said the industry must advance beyond simply collecting data towards ensuring it can move freely across systems. It should also work to establish standardized performance KPI definitions in order to eliminate variations between expected yield calculations, digital twin definitions, performance methodologies and KPI calculations in order to more accurately predict portfolio performance. Comments Please login to comment The June issue of pv magazine Global is out now! Available in print and digital – get your copy today! Thursday, July 9, 2026 11:00 am – 12:30 pm CEST, Berlin, Paris, Madrid Thursday, June 18, 2026 2:00 pm – 3:00 pm CEST, Berlin, Paris, Madrid A two-day conference in Austin, Texas, bringing together leaders in US solar manufacturing, equipment specification, and factory execution. Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects. April 01 – August 31, 2026 pv magazine USA hosts its third multi-day virtual event on advancing U.S. solar and energy storage markets, covering financing, supply chains, and distributed energy’s role in grid resilience.
No matter which way you slice it, the farm economy is in a challenging place right now. Farmers are running the numbers on their operations. For many, the numbers aren’t adding up. Fertilizer costs are up. Fuel isn’t coming down. Equipment payments aren’t stopping. As the margins that keep a farm in the family keep getting thinner, many farmers are evaluating their options. Not to get rich. Just to stay afloat. One of those options is putting solar panels on a portion of the farm acreage. Not replacing crops or giving up farming. Just using a small part of what they own to generate steady income and lower their power bills. For a lot of farmers right now, solar is not a political issue or environmental statement. It’s a way to make the math work. As president of CB solar, I’ve helped plenty of farms here in Iowa install solar arrays on their property, and I’ve seen first-hand how solar brings stability to farm families. More: Why Iowa farmers need competition, not another bailout | Opinion Too many debates in Washington around solar and agriculture treat it like a choice between food and energy. But increasingly, farmers are doing both. For farmers facing unpredictable markets, weather, and input costs, a long-term solar lease and lower electricity bill can provide something rare: stability. That’s why programs like the Rural Energy for America Program (REAP) matter. REAP has helped farmers install energy systems, cut costs, and invest back into their operations. This is not a partisan issue. Farmers don’t ask whether something is Republican or Democrat. They ask whether it works. REAP has worked. Now, as the Senate takes up the farm bill, lawmakers face a choice: Protect programs like REAP that help farmers lower long-term costs or cut a valuable program for rural Americans. Cutting this critical program would be a mistake. At a time when President Donald Trump is focused on lowering costs and strengthening domestic energy, helping farmers generate their own power checks every box. Energy produced on American farms, by American landowners, is about as local and secure as it gets. More: Farm bill draft has warts; Iowa delegation should fix it | Opinion That doesn’t mean every project should move forward without scrutiny. But the answer isn’t to take options off the table entirely. The answer is to make sure those options are available and workable through the farm bill. Rolling back REAP wouldn’t be a victory for rural America. It would simply make it harder for farmers to use their own land and keep their operations afloat. This is about whether Washington will help ensure the folks that know their land the best get a chance to do what they’ve always done: tend to their land and provide for their communities. Tyler Bacon is president of CB Solar of Des Moines.
On Wednesday, the Maryland Board of Public Works approved a little over $8M for projects in five counties and Baltimore City. The majority of those funds – $6.7M – came from grants by the Maryland Department of the Environment, with $6.5M of that going to Baltimore County for potable water infrastructure improvements.
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