BLACKSBURG — The Blacksburg Transit facility will soon feature an 867-kilowatt solar power system as the town works to integrate more sustainable operations. The Blacksburg Transit facility where a company will soon install 1,469 solar panels. Ethan Hunt (540) 381-1678 ethan.hunt@roanoke.com
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Three East Yorkshire schools have reduced their energy bills after installing solar panels on their roofs. Withernsea High School, Kingsway Primary and Marshlands Primary in Goole are expected to save a total of about £71,000 a year and cut CO2 emissions by 75,000kg annually. The solar arrays were paid for by a £218,000 grant from the Department for Education. Mark Crofts, headteacher at Withernsea High School, said staff, pupils and parents had welcomed the upgrade. "At a time when school funding is more challenging than ever, this initiative is helping us to save money while driving something that is critically important for our children's futures," he told the Local Democracy Reporting Service. East Riding of Yorkshire Council measures carbon emissions across all school and corporate sites as part of national targets to achieve net-zero carbon emissions by 2050. Listen to highlights fromHull and East Yorkshire on BBC Sounds, watch the latest episode of Look North. Download the BBC News app from the App Storefor iPhone and iPad orGoogle Play for Android devices Enforcement officers in Hull say abuse and inappropriate behaviour has become their "normal". Spread across thousands of ordinary homes, Vermont's virtual power plant has become its largest power source. It's protecting owners from outages and providing cheaper, cleaner energy. Highlands College and Jersey Electricity have partnered to launch the Green Skills Academy. The new facility will manufacture parts for offshore wind farms in Scottish waters and for overseas markets. The 43,000 panel solar farm will power 9,400 homes and the council expects it to bring in more than £1m. Copyright 2026 BBC. All rights reserved. The BBC is not responsible for the content of external sites. Read about our approach to external linking.
Fotowatio Renewable Ventures (FRV) has commissioned its first utility-scale battery project in Australia with the 100 MW / 200 MWh Terang battery energy storage system (BESS) now operating at full capacity. FRV Australia Chief Executive Michael Steiner said the commissioning marks a crucial milestone for company. It is FRV’s first standalone battery energy storage project in Austraia, increasing its portfolio of operational assets in the country to nine and adding dispatchable energy capacity to the developer’s predominantly solar generation portfolio. “The commissioning of Terang marks a defining moment for FRV Australia,” he said. “The project demonstrates our ability to develop and operate utility-scale dispatchable energy infrastructure that supports Australia’s energy transition.” FRV said the 100 MW / 200 MWh battery, sited near the town of Terang in Victoria’s southwest, will help strengthen the stability and resilience of the National Electricity Market (NEM) and support the state’s efforts to achieve its target of 65% renewable energy generation by 2030. The project received $7 million (USD 4.87 million) through the Victorian government’s Energy Innovation Fund to support the deployment of grid-forming inverter technology designed to supply system strength services to the network. “It provides critical firming capacity during peak hours while helping to strengthen grid reliability,” Steiner said. The Terang facility incorporates 48 SolBank 3.0 battery containers supplied by Canadian Solar subsidiary e-Storage, and 38 inverters from German manufacturer SMA. Canadian Solar served as engineering, procurement, and construction (EPC) contractor for the project, with Sydney-headquartered TEC-C delivering the balance-of-plant works. Terang forms part of FRV Australia’s growing BESS portfolio that includes a 2.5 MW / 5 MWh battery delivered as part of the Dalby Hybrid Power Plant in Queensland. The company is also building the 250 MW / 500 MWh Gnarwarre battery in Victoria’s south, with completion targeted by the end of 2027. FRV Australia, owned by Saudi energy company Abdul Latif Jameel Energy and Canadian pension fund Omers, also has a pipeline of standalone BESS and solar-battery hybrid projects under development in New South Wales (NSW), Victoria and Queensland. In addition, the company has more than 1.3 GW of solar assets built or under construction across 10 projects in Australia, including the 300 MW Walla Walla solar farm in the New South Wales Riverina. 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
Pisgah Energy has completed a 680-kW solar system for the Sisters of Mercy of the Americas in Belmont, North Carolina. During project development, Pisgah Energy discovered that City of Belmont land development ordinances did not allow for the installation of ground-mounted solar projects. Over many months, the Pisgah Energy team and Sisters of Mercy staff…
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Few industries in India have scaled as quickly as solar manufacturing. Backed by ambitious renewable energy targets, a rooftop programme for households, import duties on foreign modules, and the Approved List of Models and Manufacturers (ALMM), domestic module capacity has multiplied in just a few years. For investors, a Solar Panel Manufacturing Plant Setup in India offers entry into a strategic, policy-backed sector, though one that now rewards technology choice, cost discipline, and cell integration far more than it did when capacity was scarce. Capital needs depend on line capacity, cell technology, and the degree of automation. For a module assembly plant of roughly 100 MW to 2 GW, the Solar Panel Manufacturing Plant Cost typically falls between INR 25 crore and INR 400 crore, while backward integration into cells raises the figure several times over. Solar cells alone make up most of the operating cost of a module-only plant, so cell sourcing is the decision that shapes margins more than any other. At healthy utilisation, a competitive plant can deliver a net profit margin of 5 to 12% and an IRR of 14 to 22%, with payback usually reached within 3.5 to 5.5 years. This guide is written for investors weighing how to start a Solar Panel manufacturing plant in India. It explains the product and technologies, the demand picture, production flow, machinery and raw materials, site and infrastructure planning, a detailed cost and financial breakdown, the certifications and approvals involved, and how a DPR brings everything together into a plan that lenders can evaluate. The snapshot tells two stories. Demand is large and policy-supported, but enlisted module capacity has grown far faster than domestic cell capacity, and faster than annual installations. That gap is the key to planning: plants that secure competitively priced cells, move to newer technologies, and serve domestic-content (DCR) demand are well placed, while generic module-only capacity faces tighter margins. The rest of this guide works through those choices. Indicative Project Cost in India (2026) These ranges are a starting point for early planning. Actual returns depend on cell prices and availability, the technology the line is built for, how quickly the plant achieves BIS and ALMM listing, and whether offtake is secured with developers, EPC companies, or rooftop channels. A site-specific Solar Panel Feasibility Report narrows each of these assumptions to your chosen capacity, technology, and location. Table of Contents Solar panel manufacturing, more precisely called PV module manufacturing, is the assembly of solar cells into a sealed, framed, weatherproof unit that generates electricity for 25 years or more. Cells are interconnected into strings, laid up between glass and encapsulant layers, laminated under heat and vacuum, framed, fitted with a junction box, and tested for power output and safety. The quality of materials and process control directly determines a module's efficiency, reliability, and warranty performance. The value chain runs from polysilicon to ingots, wafers, cells, and finally modules. Most new entrants start at the module stage, which needs the least capital and the shortest build time, and consider cell integration later. A well-run Solar Panel Manufacturing Plant can sell into several channels at once: utility-scale developers, EPC contractors, commercial and industrial rooftops, residential installers, and, for qualified producers, export markets. The Main Module Technologies in Indian Manufacturing Technology choice is the most consequential early decision, because it defines the equipment, the cell supply you need, and how long the line stays competitive: PERC is rapidly giving way to TOPCon as the industry standard, while HJT and back-contact designs occupy the premium end. Because cell technology moves quickly, a new line should be specified for current large-format wafers and TOPCon or HJT cells, with multi-busbar or zero-busbar stringing and glass-glass bifacial capability. A line built for yesterday's formats risks becoming uncompetitive well before its equipment is depreciated. Key Growth Drivers in the Indian Market Demand rests on a combination of national targets, supportive policy, and improving economics for buyers: India-Specific Market Opportunity The strongest opportunity lies in modules made with domestic cells, which qualify for DCR-linked schemes and command a clear price premium over modules using imported cells. Producers who pair module lines with cell supply, whether their own or through long-term contracts with Indian cell makers, and who invest in current technologies are best placed as enlisted module capacity continues to outpace demand. Understanding the flow helps you plan equipment, cleanroom-grade floor areas, and where yield losses arise. Module assembly is a highly automated sequence in which cells are tested, interconnected, encapsulated, and framed, with inspection built into several stages. Dust control, humidity management, and careful handling of fragile cells all affect yield. The Solar Panel Manufacturing Process Flow The sequence below describes a typical automated module line. Integrated plants add a cell line upstream, which involves a far more complex chemical and thermal process and a much larger investment. Two factors decide profitability across this flow. The first is yield: cells are the most expensive input, and every cracked cell or rejected module is a direct loss, so automated handling and inline EL inspection pay for themselves quickly. The second is power binning, because modules are sold by the watt, and a line that delivers consistently high output per module earns more from the same materials. Lamination is typically the throughput bottleneck, so laminator capacity usually sets the line's rated output. The main inputs are solar cells, glass, encapsulant, backsheet or rear glass, aluminium frames, and junction boxes. Cells dominate cost and determine both the module's efficiency and its eligibility for domestic-content schemes, so cell sourcing is the heart of the supply plan. Because cells account for well over half of operating cost, the gap between imported and domestic cell prices, and the premium that DCR modules command, largely decides a plant's margin. Imported cells attract customs duty, while domestic cells remain in short supply relative to module capacity. Long-term supply contracts, qualified alternative suppliers for glass and encapsulant, and a clear strategy on DCR versus non-DCR output are therefore central to the business plan. Site selection for a module plant is shaped by access to ports for imported inputs, proximity to major solar markets, reliable power, and state incentives. Because modules are heavy and fragile, freight to project sites is a meaningful cost, and several states now offer dedicated incentives and ready land in manufacturing parks. Choosing the Best Location for Solar Panel Manufacturing Plant Setup Gujarat leads by a wide margin, with established clusters around Mundra, Dholera, and Surat, port access for imported cells and glass, and a deep supplier base. Rajasthan offers proximity to the country's largest solar parks, while Tamil Nadu, Karnataka, and Telangana combine incentives, skilled manpower, and export-friendly logistics. The final choice should weigh inbound input logistics, outbound freight to target customers, and the value of state capital subsidies and power tariff concessions. Quality, Certification and ALMM Readiness Market access for a module maker depends on certification as much as on price. Modules must be registered with BIS against the relevant Indian standards, and most projects require the manufacturer and its models to be enlisted on ALMM, which involves a factory inspection and verification of manufacturing capability. That means a controlled production environment, calibrated test equipment, documented quality procedures, traceability from cell to finished module, and reliability testing. An experienced Solar Panel Manufacturing Consultant in India can help plan the line, quality system, and certification sequence so the plant is ready for enlistment soon after commissioning. Infrastructure Requirements (Mid-Sized Plant) Controlled production halls, reliable power, and ample warehousing form the backbone of a module plant. Planning floor space and power capacity for a second line, or for future cell integration, from the outset avoids costly rework, since most successful Indian manufacturers have expanded in phases. Module assembly is highly automated, and the equipment set covers cell handling, stringing, layup, lamination, framing, and testing. Line capacity is usually quoted in MW or GW per year and is set largely by the stringers and laminators. The main machinery is summarised below. Equipment should be chosen for the technology you intend to run for the next several years, not the one that is cheapest today. Stringers and laminators compatible with large-format TOPCon and HJT cells and glass-glass modules protect the line against rapid obsolescence, while inline EL testing and accurate sun simulators protect yield and customer trust. The tables below break down capital and operating costs for a mid-sized module assembly facility in India. The final Solar Panel Investment Cost for your project will depend on line capacity, technology, automation level, location, and whether cell manufacturing is included. Capital Expenditure (CapEx) Cost Structure Machinery dominates the capital budget, and its specification, particularly technology compatibility and automation, has the biggest long-term effect on competitiveness. Working capital is also significant, since cells and glass must be bought ahead of sales and project customers often pay on milestones. A detailed Solar Panel Business Plan should model these items separately, along with the option of phasing in cell production, so that capacity and technology decisions rest on realistic numbers. Operating Expenditure (OpEx) Cost Structure With materials making up the large majority of operating cost, this is essentially a procurement-and-yield business. Margins move with cell and glass prices, so the operating model should track these closely and test profitability under different cell price scenarios, DCR premiums, and utilisation levels. Small improvements in yield and power binning have an outsized effect on the bottom line. Based on analysis of a mid-sized module assembly facility, the financial profile is sound but increasingly competitive. The profitability of Solar Panel manufacturing business in India depends heavily on securing cells at good prices, producing DCR modules, running current technology, and keeping utilisation high in a market where enlisted capacity exceeds annual demand. Technology, cell sourcing, and offtake determine where a plant lands within these ranges. A line assembling older-technology modules from imported cells competes largely on price and sits at the lower end, while a plant producing high-efficiency DCR modules with secured offtake can move toward the upper end. Because per-watt margins are thin, utilisation and yield carry unusual weight. Returns can be strengthened by signing offtake agreements with developers and EPC firms before commissioning, building DCR capability through domestic cell contracts or integration, specifying lines for TOPCon and HJT, targeting rooftop channels where DCR modules command a premium, and pursuing export customers seeking non-Chinese supply. Strong quality systems that minimise warranty claims protect both margins and bankability. Key Risks and Mitigation The main risks are overcapacity and price pressure, cell supply and price volatility, rapid technology change, and policy shifts. Price risk is reduced by long-term offtake and a focus on DCR and premium segments; supply risk by multi-source cell contracts or integration; technology risk by specifying flexible, current-generation equipment; and policy risk by tracking ALMM, duty, and scheme changes closely. Promoters frequently work with a Solar Panel Business Plan Consultant in India to test these scenarios before committing capital. Solar module manufacturing is a certification-driven business, and approvals determine which projects a plant can supply. Promoters setting up a Solar Panel Manufacturing Plant in India generally need the following: BIS registration and ALMM enlistment are the critical items, because without them a plant cannot supply most of the Indian market. Planning the testing laboratory, quality documentation, and inspection readiness alongside construction helps shorten the gap between commissioning and first commercial sales. State incentive applications should also be filed early, as they often require approvals before investment is made. Note: The exact approvals, registrations, licenses, and certification requirements may vary depending on factors such as plant location, technology, target projects, export markets, and applicable regulations. Businesses are advised to undertake a detailed regulatory assessment during the project planning stage to ensure full compliance and timely implementation. Several recent developments shape the outlook for new entrants: The direction is clear: the market increasingly rewards integration, current technology, and domestic-content capability rather than raw assembly capacity. New entrants who plan for these realities, whether through cell partnerships, phased integration, or a focus on premium and DCR segments, will be best positioned through the rest of the decade. A detailed DPR provides a structured roadmap for the venture, from market demand and technology selection to machinery, layout, certification, and economics. It helps investors decide the right capacity and product mix, estimate capital and operating expenditure, assess profitability, and identify risks before any funds are committed. At its core is a detailed Solar Panel Financial Model covering revenue by product and channel, per-watt cost build-ups, cell price scenarios, cash flows, break-even, return on investment, and payback. Banks and investors rely on this model to judge long-term viability, which is why many promoters appoint a Solar Panel Plant Project Report Consultant in India to prepare the report and test its assumptions against current market data. For a solar project, a strong DPR also sets out the cell sourcing strategy, the technology roadmap, the certification timeline, and the offtake plan, which together are the factors most likely to decide success. By modelling utilisation against realistic demand and stress-testing margins against cell price movements, the report turns a competitive, fast-moving opportunity into a plan that lenders and partners can trust.
Construction has started on Blackwater Solar, a 200-MW project in Roosevelt County, New Mexico. Project developer Ørsted also announced a $100,000 contribution to Playa Lakes Joint Venture (PLJV) to support the restoration and conservation of local wetlands near the project site. Located between Portales and Clovis, Blackwater Solar will generate electricity within the Southwest Power Pool…
Sep 30, 2026 | Featured, News LAFOLLETTE, TN (WLAF)- At the forefront of the mission of the La Follette Fire Department is public safety and protecting the environment. That main priority was on full display Tuesday afternoon and evening when LFD Firefighters responded to the call of a hot, swollen large lithium battery in a neighborhood. LFD Chief Jimmy Pack said the battery weighs 100 pounds, and the initial concern was that they could end up dealing with a thermal incident. That’s when batteries overheat, like this one, posing serious risks such as fire or even explosion. The initial call came in to La Follette 911 Dispatch a little after 5 pm Tuesday. “I can’t thank our 911 dispatchers for getting us the aid sent to us we needed,” said Pack. Around 9 pm, Tuesday, the chief explained that “we are moving the battery to a secure location until it discharges, and then it will be properly deposed of. We are taking all precautions to make sure there is no contamination”. As the hours long tense situation eased up, Pack expressed his appreciation. “I would like to thank my firefighters for a job well done and thanks to the City Administrator Stan Foust for all the support along with La Follette Public Works, Campbell County EMA and TEMA. It all began when the battery, used with a solar panel in a van parked in the driveway of a home in Linden Park, Riverview Drive, became hot and swollen. “We were able to get this large battery off to itself and keep everyone away from its fumes. We covered the solar panels to keep any more energy from being generated,” said Pack. Because LFD does not have the resources to properly and safely dispose of a battery of this size, technicians from Tennessee Emergency Management (TEMA) were called to assist. Before acquiring the home, the homeowner lived in the van using the solar panels for energy, stated Pack. Here is the account of the developing story from Tuesday afternoon: “TEMA is here now (7:10 pm), and the battery is still way too hot to move, and TDEC is on its way to assist,” said LFD Chief Jimmy Pack. He adds that everyone is safe, and his men and trucks will remain on scene until all is clear. “What’s gonna happen next is an independent contractor will come in and properly dispose of the battery,” said Chief Pack. Already into hour two, Pack notes that this could take several more hours. The call initially came in the the La Follette 911 Center a little after 5 pm. Firefighters with the La Follette Fire Department were called to a van in the driveway of a home, at Linden Park late Tuesday afternoon. The emergency was that a large lithium battery that hooks to solar panels swelled and overheated in the back of a van. “We were able to get the battery off to itself and keep everyone away from its fumes. We covered the solar panels to keep any more energy from being generated,” said LFD Chief Jimmy Pack. LFD does not have the resources to properly and safely dispose of a battery of this size. As a result, technicians from Tennessee Emergency Management (TEMA) are on their way to the scene on Riverview Drive to take the battery away, according to Pack. Before acquiring the home, the homeowner lived in the van using the solar panels for energy, stated Pack. (WLAF NEWS PUBLISHED-09/29/2026-6PM-UPDATED 09/30/2026-6AM) Slamdot
Repowering existing solar power plants could unlock significant solar and dispatchable battery capacity by 2040, according to a new Crux and Foundry-Logic report According to the assessment, existing land, permits and grid connections could help reduce project costs and development time C&I distributed generation offer near-term opportunity, while utility-scale projects gain a larger share over time Repowering existing solar power plants in the US offers a huge opportunity for the country to meet its rising electricity demand with solar and storage. According to a new report by Crux and Foundry-Logic, this could unlock the equivalent of 67 GW AC of new solar and 91.7 GW AC of dispatchable battery storage capacity by 2040. In the interim, by 2030 repowering could drive equivalent of 9.6 GW AC of new solar and 13.1 GW AC of dispatchable battery capacity, rising to 29 GW AC and 41.4 GW AC by 2035, respectively. The report writers see repowering as an opportunity at a time when the first generation of US solar plants come to an end of their life. This is happening at a time when the grid can least afford to lose capacity. It identifies two key factors supporting the case for repowering. First, technological advances mean today’s solar modules deliver 50% more power from the same footprint, while battery costs have fallen 90% over the past decade. Battery pairing is also increasing in the US. According to the report, 22% of new solar capacity planned for H1 2026 is designed to co-locate battery energy storage, while the number goes up to 48% of projects scheduled for 2029. Second, repowering allows plants to retain existing land, permits, and grid connections, avoiding lengthy new development processes and bringing down capex. The report estimates that a full repower costs about 20% less per watt than building a new project. Although there will be additional costs related to removing existing modules, it will help avoid major costs such as land acquisition, grid interconnection applications, and substation construction. Batteries can also use existing grid connections, making repowering an opportunity for older plants to add storage at lower cost. According to the report, the near-term repowering opportunity is largest in the commercial and industrial (C&I) distributed generation (DG) segment. This segment is expected to account for 52% of the total US solar repowering capacity potential by 2030. Together DG and residential solar account for 5.3 GW AC of 9.6 GW AC of the estimated potential in 2030, according to the analysts. By 2040, utility-scale projects are expected to account for nearly two-thirds of the 67 GW AC opportunity as older plants reach repowering age. California, North Carolina, and Arizona lead the market in 2030. The opportunity is initially concentrated in a few states but is expected to spread across more of the US over time. For battery storage, it is California, North Carolina and Arizona that offer the greatest opportunity from solar powering in 2030. The solar repowering market, according to the analysts, is expected to be worth $10.8 billion annually in 2030, growing to $51.8 billion by 2040 at a compound annual growth rate (CAGR) of 17%. They expect cumulative spending at around $346 billion between 2026 and 2040. Battery additions or replacement represent nearly half of the spend, as per the report titled Recharged: Repowering America’s Solar Fleet with Storage for a New Era of Demand. Repowering can extend a solar plant’s operating life by 15 years or more, often beyond the terms of its existing power purchase agreement (PPA) and land lease. Hence, the writers recommend owners to extend or replace these agreements, depending on their existing terms. The report says solar repowering projects will generally no longer qualify for federal solar tax credits from 2028, unless they meet the applicable construction-start (July 4, 2026) or commissioning (in service by December 31, 2027) deadlines. However, battery storage added to existing solar sites can qualify independently for the full investment tax credit (ITC) under Section 48E through 2033, phasing to 75% in 2034, and 50% in 2035. These credits can also be sold under transferability mechanism. The complete report is available for free download on Crux’s website. Wood Mackenzie expects more than 2.5 TW of existing solar and wind energy projects to reach the end of their operating lives by the 2040s. This will create a major replacement market, accounting for 23% of all solar installations globally (see 2.5 TW Aging Renewables To Drive New Solar, Wind Demand). TaiyangNews 2024
The Norwegian Energy Regulatory Authority (NVE) is proposing a simplified connection process for small renewable generation facilities, including solar PV systems. NVE refers to the proposed change, aimed at existing grid customers in low-voltage distribution networks, as an ‘inform and install’ process. It requires a customer or installer to inform the grid company of a planned installation. The grid company will then assess if the connection is operationally sound and notify the customer in writing within one month of any concerns. If the grid company does not do so within the one month deadline, the proposed change allows the customer to install and use the facility and consider the permit as granted. “This gives customers a clearly defined right to rapid clarification, and a better basis for deciding on investments in local production,” NVE’s update says. “The aim is to make it easier and more predictable to establish local, renewable generation without compromising delivery quality and grid operation.” The updated process is expected to apply to systems with an installed capacity of up to 6 kW for single-phase connections and up to 11 kW for three-phase connections. NVE says the limit applies per metering point, including where several end users share a connection point, such as multi-family homes. “We are ensuring that most typical household installations are covered, while also limiting the risk of voltage problems in the network” explained Torfinn Jonassen, NVE section manager. “This will make it easier for households, housing associations and other end customers to use, for example, solar cells.” A consultation document has been published and is open for comments until November 20. Earlier this month, Norway surpassed 1 GW of installed solar capacity. However, deployment rates have slowed in recent times, with the 43 MW of solar added across the first seven months of 2026 representing the slowest growth since 2021. Analysts have largely attributed the market contraction to a drop in residential installations, which have been almost at a standstill, largely due to Norway’s fixed electricity price for households, known as the Norgepris, removing most of the residential payback case. Earlier this year, the Norwegian Parliament ordered a study on a guaranteed minimum price for building-mounted solar power exported to the grid. Speaking to pv magazine earlier this month, Hassan Gholami, a senior consultant on solar and storage at Multiconsult, said the outcome “will largely decide whether homeowners return to the market.” 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]. 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 pv magazine USA hosts its multi-day virtual event on U.S. solar and energy storage, covering domestic manufacturing, distributed energy and the growing role of solar-plus-storage in meeting AI-driven power demand. pv magazine Session returns to NetZero Milan as Knowledge Partner, organizing and moderating a two-hour conference on the evolving global solar supply chain. Get your ticket at a discounted rate with pv magazine. Join pv magazine for an expert session exploring quality, technology and the challenges of scaling India’s solar industry. Monday, October 26, 2026 10:30 am – 11:30 am CEST, Berlin, Paris, Madrid The new ESS News magazine is here! Download your free digital copy today. The new issue of pv magazine Global is out now! Available in print and digital – get your copy today! Giovedì, 1 ottobre 2026 14:30 – 15:30 CEST, Roma
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Searching for your content… In-Language News Contact Us 888-776-0942 from 8 AM – 10 PM ET Sep 30, 2026, 09:00 ET Share this article New 200 MW solar project will help power New Mexico industry while supporting local conservation efforts AUSTIN, Texas, Sept. 30, 2026 /PRNewswire/ — Ørsted today announced the start of construction on Blackwater Solar, a 200 MW solar farm in Roosevelt County, New Mexico, marking the company’s first project in the state. The company also announced a $100,000 contribution to Playa Lakes Joint Venture (PLJV) to support the restoration and conservation of local wetlands near the project site. Located between Portales and Clovis, Blackwater Solar will generate enough electricity to power the equivalent of more than 56,000 homes annually within the Southwest Power Pool (SPP) territory. The project is backed by a long-term power purchase agreement that will help meet growing industrial electricity demand in New Mexico. In addition, Ørsted sourced solar panels for the project from domestic manufacturer First Solar, supporting American energy production and manufacturing. The project is expected to reach commercial operations date in late 2027. “Blackwater Solar marks an exciting first chapter for Ørsted in New Mexico,” said Melissa Peterson, President of Americas Onshore at Ørsted. “Blackwater Solar will generate affordable, homegrown energy while creating long-term benefits for the local area. We are honored to make our first investment in the state and look forward to being a dedicated partner to the Roosevelt County community for years to come.” As part of its commitment to being a responsible community partner and steward of the land where it operates, Ørsted is contributing $100,000 to Playa Lakes Joint Venture to restore wetlands near Melrose, New Mexico. The project will help conserve an 8.8 acre playa, a natural resource that is important to the region’s wildlife and water resources. This effort builds on Ørsted’s previous partnership with PLJV in West Texas, where the company’s support helped restore more than 700 acres of playa habitat across five counties. Eastern New Mexico is home to more than 2,100 playas, which serve as important water resources and wildlife habitat across the region. “Playa Lakes Joint Venture (PLJV) is committed to working with a diverse group of partners to conserve natural resources for the benefit of both people and wildlife,” PLJV Coordinator Rich Schultheis said. “We appreciate not only Ørsted’s financial commitment to restoring these critical wetlands, but also the shared understanding of the importance of maintaining biodiversity. It is rewarding to see Ørsted supporting bird habitat restoration and increasing the biological function of playas.” Blackwater Solar and the accompanying conservation investment reflect Ørsted’s approach to meeting growing electricity demand while creating lasting environmental and economic benefits in the communities where it operates. In addition to the conservation investment, Blackwater Solar is expected to contribute nearly $18 million in property tax revenue to Roosevelt County over its operating life, helping support local schools, infrastructure, first responders, and other public resources. About Ørsted Ørsted’s Americas Onshore business encompasses over 6 gigawatts of wind, solar, and battery storage capacity in operation across eight states. The company is one of the largest multi-technology independent power producers in the U.S., partnering with landowners and local communities to deliver affordable, reliable energy. Supported by a team of approximately 250 employees, the business develops, constructs, and operates projects serving utilities and corporate offtakers with long-term power agreements. To learn more about Ørsted in the U.S., visit us.orsted.com or follow the company on X (@OrstedUS), Instagram, and Facebook. SOURCE Orsted Ørsted, a leading global renewable energy company, today announced Old 300 Storage, a 250 MW/500 MWh battery energy storage system (BESS) in… Alternative Energies Electrical Utilities Environmental Products & Services Utilities Do not sell or share my personal information:
AUSTRALIA’S NATIONAL SCIENCE AGENCY From spatial modelling to innovative coatings and intelligent systems – CSIRO solar science is accelerating Australia’s renewable energy transition. Share By Joshua Janssen, Emily Brown19 May 20266 min read Globally, the amount of power solar PV panels can produce in ideal conditions is tipped to surpass coal next year, according to the International Energy Agency. In Australia, large-scale solar farms are projected to supply nearly 25 per cent of our electricity by 2050. That’s a long way from the nation’s first utility-scale solar farm, which officially opened in Western Australia in 2010, providing up to 10 MW of clean electricity generation. CSIRO research is ensuring renewable technology works alongside other vital industries, like agriculture, while also improving its efficiency and effectiveness through innovation in design and materials, and the integration of AI. So, what does the future look like for large-scale solar farms as they continue to transform our energy landscape? Solar farms enjoyed the highest level of acceptance of key renewable technologies among the wider Australian public, according to a 2024 survey by CSIRO. But people living out of town (in rural areas) were more likely to reject living near renewable energy infrastructure, and those surveyed reported low understanding of its impacts. Environmental impacts and concerns about waste disposal when developments were decommissioned were the two highest concerns about solar farms. There were also significant concerns about devaluing nearby properties and less land availability for farming and other land uses. New spatial modelling by researchers from CSIRO and the University of Western Sydney has revealed how impacts on agricultural profitability can be minimised. Researchers modelled 1,568 scenarios, quantifying trade-offs between solar power yield and agricultural profitability by considering factors like solar farm design, performance and distance from renewable energy infrastructure
A hot deal: landowners can earn from new solar farms.
CSIRO research scientist Dr Stephen Snow explained that impacts on prime agricultural land from large-scale solar are largely avoidable. “When siting is done strategically, high-value irrigated land and intensive cropping zones require almost zero conversion to solar,” Dr Snow said. “Instead, the land most likely to host solar is lower-profitability grazing country, where hosting solar can represent reliable, drought-proof income.” By converting marginal grazing areas instead of prime agricultural land, the impact on national agricultural profit drops from $29 million per year (or 0.03 per cent of Australia’s agricultural GDP) to just $2.6 million per year (or 0.003 per cent of Australia’s agricultural GDP). That’s a 90 per cent reduction, while generating the same amount of energy with minimal cost effects. “In suitable areas, grazing livestock like sheep under solar panels could reduce the impact even further: farmers receive compensation for harvesting the sun, while their herds and pasture are shaded,” Dr Snow said. Land use sits within a broader picture of how solar farms are designed and run. The performance of large-scale and utility-scale solar farms depends on more than size; it also depends on layout and operation of the system for consistency and efficiency. Experimental scientist Kenrick Anderson is working on planning of large-scale farms and next generation photovoltaics and said advanced models were helping grid operators better understand how a solar farm performs in real time and over its full lifespan. “Being able to better predict the output of a solar farm is incredibly important,” Mr Anderson said. “It means you can operate with confidence, rather than holding capacity back because of uncertainty.” The modelling tools can be applied at every stage – from planning solar farm layouts to maximise output per hectare, to perfecting the tracking system for the PV panels – so the panels are optimally positioned as the sun moves across the sky.
CSIRO’s Photovoltaic Outdoor Research Facility – Used for various projects investigating the performance and long-term degradation of modules, as well as tracking technology on panels to maximise output.
With the aid of this kind of modelling, solar farms can run closer to their true capability, delivering more power from the same infrastructure while improving reliability for the grid. The same modelling is critical when paired with large-scale batteries, which are becoming increasingly common on solar farms. During peak sunlight hours when many facilities must curb electricity generation due to grid constraints, batteries are now widely used to store excess energy for later use, said Mr Anderson. More accurate output predictions using models are helping operators develop strategies that ensure batteries are adequately charged and able to discharge energy to the grid when demand peaks in the late afternoon and evening. “These models can ensure batteries are available when they’re needed most,” he said. Large-scale solar farms are inevitably exposed to the elements that affect performance. “PV panels work better when they are cooler, so understanding wind patterns can inform solar panel orientation in a solar farm,” Mr Anderson said. Advanced computational fluid dynamics modelling to better understand how wind, heat and dust move across large solar arrays is helping shape how future solar farms are being built and operated. With hundreds of thousands of solar panels making up large-scale PV projects, operators face the challenge of ensuring the panels remain clean from dirt and dust to perform at their capacity and to absorb as much sunlight as possible. “We are developing new self-cleaning coatings that don’t sacrifice the anti-reflective technology crucial for PV Panels,” Mr Anderson said. “Thin, film-like coatings that repel dirt and dust, they also allow the panels to absorb energy at a higher rate.”
CSIRO’s self-cleaning coating applied to the surface of a solar module. Water beading is used to visualise the effect, repelling the dirt and dust.
That takes us down to the cell level and CSIRO’s partnership with the Australian Centre for Advanced Photovoltaics (ACAP) which includes work on silicon-perovskite tandem photovoltaics. These tandem cells are expected to deliver at least a 5 per cent efficiency gain over existing single junction silicon technology. At scale, that improvement would enable a solar farm to generate enough additional electricity to power around 1,000 more homes using the same land area as a 100-megawatt solar farm today.
Time series of CSIRO’s automated thin film deposition system used to fabricate solar cells using new materials. Top series shows the film under white light, and the bottom series shows the film under photoluminescence. Researchers use photoluminescence characterisation to monitor the film quality.
The work doesn’t stop once solar farms are built. In fact, inspecting and maintaining the panels is essential to keeping their energy output high. But the cost, safety risks and labour of doing this manually are significant. To address these challenges, CSIRO researchers are bringing AI and robotics expertise to solar farms, using AI-powered robots that can autonomously navigate large-scale sites, mapping and moving across rapidly changing terrain. The robots safely and efficiently build precise maps to digitise site conditions and use AI to develop a holistic understanding of the site, that would otherwise take weeks of manual inspection. Equipped with cameras, Light Detection and Ranging (LiDAR) and sensors, the robots can detect issues ranging from dust build-up and bird droppings to damaged wiring, loose components and dangerous hotspots within panels. “Hotspots decrease the efficiency of a PV panel over time because of the electrical and thermal imbalance they create. Solar farms benefit from early hotspot detection,” Mr Anderson said. By logging faults precisely on a digital map of the farm, the robots enable skilled workers to target only the panels that need attention, reducing maintenance costs, improving safety and helping solar farms deliver more efficient and reliable electricity output.
Robot moving autonomously through a row of solar panels, using sensors to navigate terrain.
Dr Peyman Moghadam, Senior Principal Research Scientist with CSIRO, said the long-term vision is to move beyond inspection toward site intelligence. “We a not just collecting images or 3D data. We are building the foundations for intelligent solar operations, where data from robots, fixed sensors and field systems get fused to support earlier warning, better predictive maintenance decisions and more resilient performance over time,” said Dr Moghadam. The rapid deployment of solar is an Australian success story, and collaborative solar research is advancing their next-generation development. Smarter solar operations are shaping how we run systems today – but they also raise important questions about sustainability tomorrow. The relative newness of large solar farms presents ongoing research opportunities regarding their durability and longevity while their scale ultimately brings large challenges associated with end-of-life solar PV panels and solar waste management. As we become accustomed to fields of solar panels in the landscape, future innovation will help shape a more efficient, reliable and sustainable renewable energy sector. If you are looking to partner with CSIRO, contact us here: noel.duffy@csiro.au Energy Communication Advisor Communication Advisor Communication Manager, Technology Energy Communication Advisor Communication Advisor Communication Manager, Technology We are committed to child safety and to the implementation of Child Safe principles and procedures. Thanks. You’re all set to get our newsletter We could not sign you up to receive our newsletter. Please try again later or contact us if this persists. CSIRO acknowledges the Traditional Owners of the land, sea and waters, of the area that we live and work on across Australia. We acknowledge their continuing connection to their culture and pay our respects to their Elders past and present. View our vision towards reconciliation. Find out how we can help you and your business. Get in touch using the form below and our experts will get in contact soon! CSIRO will handle your personal information in accordance with the Privacy Act 1988 (Cth) and our Privacy Policy. This site is protected by reCAPTCHA and the Google Privacy Policy and Terms of Service apply. Enter a valid email address, for example jane.doe@csiro.au A Country value must be provided First name must be filled in Surname must be filled in Please choose an option Organisation must be filled in Please provide a subject for the enquriy 0 / 100 We'll need to know what you want to contact us about so we can give you an answer 0 / 1900 We have received your enquiry and will reply soon. The contact form is currently unavailable. Please try again later. If this problem persists, please call us with your enquiry on 1300 363 400 or +61 3 9545 2176. We are available from 9.00 am to 4.00 pm AEST Monday – Friday.
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Inox Clean Energy has filed DRHP with SEBI as it plans an IPO to raise INR 10,000 crore It plans to use most of the IPO proceeds to repay or prepay borrowings while remaining will be used for general corporate purposes The company operates 3 GW of solar module capacity in India and approximately 3 GW in the US Indian renewable energy company Inox Clean Energy plans to raise INR 10,000 crore (approximately $1 billion) through a public offering. The company has filed its Draft Red Herring Prospectus (DRHP) with the Securities and Exchange Board of India (SEBI) to launch an initial public offering (IPO). According to the Inox Clean Energy’s DRHP, the IPO comprises a fresh issue of shares worth up to INR 8,000 crore and an offer for sale (OFS) of up to INR 2,000 crore. The company plans to use most of the net proceeds to repay or prepay outstanding borrowings of the company and its subsidiaries. The remaining proceeds will be allocated to general corporate purposes, subject to a cap of 25% of the gross proceeds. One of the leading names in the solar PV market, Inox had a renewable energy independent power producer (IPP) portfolio totaling 9.29 GW across India and Africa, as of August 31, 2026. This comprises 2.37 GW of operational capacity across nine Indian states, 800 MW of under construction, 2.99 GW in the pipeline and 3.13 GW of future capacity. Out of the total 9.29 GW, Inox says 6.16 GW is contracted under long-term offtake agreements. Inox counts 2.91 GW of sovereign-backed IPP portfolio under-development across African nations of Zambia, Zimbabwe, and the Democratic Republic of Congo (DRC) where it operates through SkyPower MENA, its venture with Arctic International Private Limited. The company acquired SkyPower, Sunsource Energy and Vibrant Energy platforms during fiscal 2026 (see India Solar PV News Snippets). In August 2026, it completed INR 6,000 crore acquisition of BlackRock-owned GIP’s Vena Energy India renewable energy platform that added 1 GW of operational, 1.7 GW of solar and wind, and 1.2 GWh of battery energy storage systems (BESS) assets at advanced stages to its portfolio. The dela also added 2.7 GW of solar and wind, and 1.3 GWh of BESS development pipeline. Inox also operates in the solar PV manufacturing space operating approximately 3 GW module capacity in the US, with close to 3 GW of cell capacity under construction via Inox Solar Americas. The latter acquired the assets of Boviet Solar (see North America Solar PV News Snippets). In India, Inox operates a 3 GW solar module manufacturing factory at Bavla in Gujarat based on TOPCon technology, however it plans to explore heterojunction (HJT) in the future. Inox Clean Energy has joined a growing group of Indian solar PV companies pursuing IPOs. The list includes Juniper Green Energy and Clean Max Enviro Energy, which have recently gone public, as well as Cosmic PV Power, Emmvee, and Avaada Electro, which are preparing to list (see India Solar PV News Snippets). TaiyangNews 2024
Renewable energy firm Exus Renewables North America has acquired a four-project solar portfolio totalling 715MWp from ibV Energy Partners, expanding its development pipeline across Wisconsin and Louisiana. The portfolio comprises the two-phase 310MWp Maple Grove Solar project in Barron County, Wisconsin; the 125MWp Bayou Teche Solar project in St. Mary Parish, Louisiana; and the 280MWp Bayou Chicot Solar project in Evangeline Parish, Louisiana. Get Premium Subscription Exus will advance the projects through their next stages of development following the acquisition. “The acquisition of these projects represents an important step in the continued growth of our development portfolio and reinforces our strategy of building a geographically and technologically diverse portfolio across the US,” said Jim Spencer, president and CEO of Exus Renewables North America. “These projects are particularly attractive because of their potential to interconnect quickly in markets where demand growth is outpacing available generation. We are pleased to partner with ibV, which shares our belief that successful projects are built through meaningful community engagement and strong local partnerships. We look forward to building on that foundation as we advance the projects.” The transaction builds on ibV Energy Partners’ development work and expands Exus’ portfolio of utility-scale renewable energy projects in the US. Exus Renewables North America is an independent owner, developer and operator of utility-scale renewable energy and energy storage projects in the US. The company has more than 6GW of renewable energy capacity across its portfolio, with more than 800MW in operation or under construction. The firm secured financing for a 130MW solar PV project in Portugal last year. MUFG’s European arm acted as sole mandated lead arranger, hedge provider, facility agent and account bank. Exus did not disclose the value of the financing. Meanwhile, ibV Energy Partners, the US subsidiary of German renewable energy developer ib vogt, is active across 18 states. The German firm has a global development pipeline of around 29GWp of solar PV, 9.7GW of battery energy storage systems (BESS) and 1.9GW of wind, with nearly 574MWp of solar, 29MW of BESS and 69MW of wind capacity currently under construction, according to the company.
Throughout the first six months after the expiration of the residential ITC, homeowners still found a clear path to savings through solar and storage, according to the “23rd EnergySage Intel: Home Electrification Marketplace Report,” released today. The report analyzed millions of transaction-level data points from homeowners shopping on EnergySage between January 1 and June 30,…
India’s proposed push into polysilicon manufacturing is aimed at closing the most important gap in its domestic solar supply chain. The country has rapidly expanded its ability to make solar modules and cells, but remains dependent on imports for polysilicon, the material at the beginning of the manufacturing process. The policy question now is whether incentives can create an upstream industry that is large, competitive and technically capable enough to support the rest of the chain. The Ministry of New and Renewable Energy is working on an incentive scheme for domestic polysilicon manufacturing. An initial proposal was intended to support more than 10 GW of capacity, while a later proposal discussed a target of at least 30 GW by 2030. The final scheme has not yet been announced, and its incentive rates, eligibility rules and implementation structure remain undecided. That uncertainty matters because polysilicon is not simply another component in a solar panel. It is one of the first building blocks in the chain. Polysilicon is converted into ingots and wafers, which are then used to manufacture solar cells before the cells are assembled into modules. A country may therefore have substantial module-making capacity while still depending on overseas suppliers for the material that enables the process to begin. India’s existing capacity shows the imbalance. According to the renewable energy ministry figures cited in the report, the country has more than 213 GW of solar module manufacturing capacity and around 32 GW of cell manufacturing capacity. Against that scale, the absence of significant domestic polysilicon capacity leaves the upstream part of the industry exposed to imported supply. The result is a solar manufacturing system that is expanding strongly at its visible, finished-product end but remains incomplete at its foundation. The government’s latest proposal represents an attempt to move from assembling or producing downstream components towards building a more integrated industrial chain, running from polysilicon to ingots, wafers, cells and modules. That shift also explains the emphasis on China. India currently relies heavily on China for polysilicon imports, according to the report. This dependence creates a vulnerability for Indian manufacturers if international supply is disrupted or prices change sharply. Domestic production would not automatically eliminate exposure to global markets, but it could reduce dependence on a single dominant external source for a critical input. The policy is being considered on the production-linked incentive model. Such a structure would connect government support to manufacturing output or specified production milestones, although the report does not provide the proposed rates or conditions. The design of those conditions will be central to determining whether the scheme produces durable industrial capacity or only a short-term increase in announced projects. The investment requirement is already significant. MNRE Secretary Santosh Kumar Sarangi said setting up polysilicon plants along with metallurgical-grade silicon could require investment of around Rs 850 crore per GW. At the scale discussed by the government, the capital requirement would be substantial even before considering the costs of technology, energy procurement, plant operation, logistics and quality control. The figure indicates why the sector is unlikely to expand solely through fragmented private investment without a clear policy framework. The government is pursuing this upstream effort alongside a separate target for ingot and wafer manufacturing. India is seeking at least 80 GW of domestic ingot and wafer capacity by June 2028. Taken together, the two proposals show that the policy is not focused only on producing more finished panels. It is intended to build several linked stages of the manufacturing process within the country. The sequence is important. If polysilicon capacity expands without corresponding ingot and wafer facilities, the supply chain would remain incomplete. If downstream cell and module factories grow faster than upstream production, manufacturers would continue to rely on imports for essential inputs. The targets therefore need to function as connected industrial planning rather than as separate capacity announcements. Industry commentary cited in the report reinforces this point. Vinay Thadani, director and chief executive of GREW Solar, said India had progressed in modules and cells but still faced a distinct gap in polysilicon and wafers. GREW Solar is planning to establish 8 GW of ingot and wafer manufacturing capacity, he said. His comments place the policy discussion within the investment decisions already being considered by manufacturers. Thadani also cautioned that domestic manufacturing should not be defined only by import reduction. He said long-term cost competitiveness would depend on scale, technology, operational effectiveness and competitive energy procurement. That is a significant qualification because polysilicon production is not merely a capacity-building exercise. A plant can be located in India and still struggle if its production costs are not competitive or if its technology cannot meet the requirements of modern solar manufacturing. Energy procurement is particularly relevant to the economics of the proposed industry. The report does not provide a detailed energy model for polysilicon plants, but it identifies energy costs as one of the factors industry considers important for competitiveness. This means the solar manufacturing policy is also connected to the country’s power system: the availability, price and reliability of electricity will influence whether domestic upstream production can compete with imported material. The same principle applies to scale. The government is considering at least 30 GW of polysilicon capacity by 2030, but the report does not establish how much of that capacity has secured financing, technology or land. Nor does it identify the companies that would build the proposed facilities, apart from GREW Solar’s stated plan for ingot and wafer production. The target is therefore a policy ambition, not evidence that the capacity already exists or is under construction. This distinction is important for assessing India’s manufacturing position. Announced capacity, installed capacity and operational output are different measures. The figures of more than 213 GW of module capacity and around 32 GW of cell capacity describe the manufacturing base cited by the ministry, but they do not, on their own, show how much each facility is producing or how much of the domestic market is being supplied by local inputs. The proposed polysilicon scheme will eventually need transparent milestones if its progress is to be measured beyond headline capacity numbers. The wider policy objective is resilience. A more integrated domestic chain could give Indian manufacturers greater control over supply, reduce exposure to external disruptions and create stronger links between different stages of solar production. It could also change the nature of the domestic industry by encouraging investment in materials and industrial processes rather than concentrating mainly on final assembly. But resilience and cost are not automatically aligned. Producing more components domestically may reduce one form of dependence while increasing costs if plants operate below efficient scale or use expensive inputs. The policy challenge is to support the creation of strategic capacity without insulating inefficient production indefinitely. The final scheme’s design will determine how that balance is attempted. There is also a timing challenge. India’s target of at least 80 GW of domestic ingot and wafer capacity by June 2028 comes before the proposed 30 GW polysilicon target for 2030. Unless the different stages are planned and commissioned in coordination, manufacturers may continue to rely on imported polysilicon even as domestic wafer capacity expands. The dates indicate the need for sequencing, although the supplied report does not provide a detailed implementation timetable. For cities and the built environment, the policy matters because solar manufacturing is tied to the future supply of electricity infrastructure. More domestic capacity could support the deployment of solar generation, but the report does not establish that it would directly lower panel prices or accelerate installations. Those outcomes would depend on production costs, demand, financing, procurement and the performance of the factories themselves. What the evidence confirms is that India has built substantial downstream solar manufacturing capacity while retaining a critical upstream dependence. The Centre’s proposed polysilicon incentive scheme is an attempt to address that structural gap, supported by parallel targets for ingot and wafer production. What remains uncertain is the final policy design, the firms that will participate, the technology and energy costs involved, and whether announced capacity will translate into competitive operating plants. Those will be the measures to watch as India moves from a module-focused manufacturing strategy towards a fuller solar industrial chain.
Grid-scale EPC Linxon, power electronics manufacturer Hitachi Energy and tracker producer FTC Solar are packaging their services for solar projects in North America. “The energy transition is no longer constrained by demand,” Stefan Reisacher, CEO of Linxon. It is increasingly constrained by execution capacity, supply chain availability and the industry’s ability to scale. This collaboration…
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Date: A typical solar panel weighs about 11.6 kilograms. Roughly two-thirds of that is glass, and the aluminum frame accounts for another eighth. By weight, those two materials are most of the module. By value, they are nearly beside the point. Almost all of the money locked inside a crystalline silicon panel sits in a thin metallic contact layer that makes up about 0.03 percent of its mass. That layer is silver, and it is the reason solar panel recycling has become one of the most closely scrutinized problems in clean energy. It is also the reason so little of it is currently happening. Table of Contents A solar cell generates electricity when light knocks electrons loose inside a silicon wafer. To collect that current, manufacturers print a fine grid of silver paste onto the front and back of every cell, then fire it into the surface. The finished grid is measured in micrometers. Because it is so thin, it is easy to treat as a rounding error. Researchers at Germany’s Fraunhofer Center for Silicon Photovoltaics have published per-module value estimates that suggest the opposite. Presented in 2026, their figures break down a standard 11.6-kilogram crystalline silicon module like this: Source: per-module estimates from Fraunhofer CSP presented by Dr. Andreas Obst, 2026. Silver loadings vary with cell design and module vintage, and some analyses put the mass share higher. Silver is the smallest line in the table and the largest number. It is worth more than the glass, the frame, and the silicon cells combined, even though those three account for roughly 83 percent of the module’s weight between them. That inversion is the whole story. A panel is a heavy object whose economics depend on a trace material, and trace materials are the hardest things to recover from a bonded laminate. The gap is not subtle. Recycling a utility-scale module in the United States costs between $15 and $45. Sending that same module to the landfill costs between $1 and $5. Philip Kwong of the University of Adelaide, whose review of photovoltaic recycling technologies appeared in the journal Waste Management, describes the trap plainly: recovered materials are generally worth less than the cost of collecting, transporting, dismantling, and processing the modules, and for most mainstream crystalline silicon recycling, commercial viability without extended producer responsibility mandates, landfill restrictions, or public subsidies remains difficult. The materials are not worthless. Recovering them at usable purity is what costs money. Most commercial lines today do what First Solar calls bulk recycling: they detach the aluminum frame and separate the glass, then stop. Silver and high-purity silicon, the two materials that carry the value, largely end up in mixed residue. Recovering silver is not a mechanical problem. It is finely dispersed through the cell metallization and sealed inside the laminate, so it takes either a hydrometallurgical process, which leaches it out chemically, or a pyrometallurgical one, which burns off the encapsulant at high temperature. Neither is cheap. Fraunhofer CSP’s own process development work suggests a dedicated hydrometallurgical line needs to process several thousand tonnes of solar cells a year before its capital cost makes sense. Kwong’s timeline for that changing is measured in years, not quarters. Under current policy settings and waste growth, he projects silver recovery becoming commercially viable in the early to mid-2030s and high-purity silicon in the mid-2030s. Even then, the numbers work only in specific niches where labor, reagent, and energy costs stay low. Researchers have separately been working on recovery routes for the silicon itself, including methods that aim to return wafers close to their original quality. The stakes go beyond waste disposal. Obst estimates the solar industry consumed roughly 6,000 tonnes of silver in 2023, against global mine production of about 30,000 tonnes that year. Silver use per gigawatt of installed capacity has fallen steeply, from around 200 tonnes per gigawatt-peak in 2006 to under 30 today, but deployment has grown faster than that thrifting. Yansong Shen, who directs the ARC Research Hub for Photovoltaic Reliability and Sustainability at the University of New South Wales, has said that without continued silver-thrifting, copper substitution, and large-scale recycling, most currently known silver reserves could be consumed within 25 years. Panels installed during the boom years of the 2010s were sold with 25- to 30-year performance warranties. Those warranties now function as the industry’s calendar. In a 2026 update to its end-of-life analysis, IRENA projects that the cumulative weight of retired solar panels will pass 12 million tonnes by 2035 and exceed 200 million tonnes by 2050 under a 1.5°C pathway, a roughly sixteen-fold increase between those two dates. Annual volumes are expected to top 3 million tonnes by 2035 and 25 million tonnes by 2050. The projection assumes panels last 25 to 30 years, and it accounts for the fact that many will be replaced early by newer, more efficient models rather than simply failing. What makes the trend unusual is its share. Solar panel waste is less than 1 percent of global electronic waste by weight today. By 2050, IRENA expects it to exceed 21 percent. Europe offers an early look at what collection looks like in practice. Eurostat figures compiled for the IEA-PVPS Task 12 report on module recycling show that 18 European countries collected 48,395 tonnes of photovoltaic module waste in 2022. That infrastructure exists largely because the European Union has regulated panels under its Waste Electrical and Electronic Equipment Directive since 2012. There is one anomaly in all of this that nobody has explained. German facilities ought to be crowded with subsidy-era panels, yet Fraunhofer CSP has found that the volume of waste arriving at them actually fell in recent years, and attempts to trace the shortfall through customs statistics did not close the gap. “Where are those modules?” Obst said. “I have no idea.” For anyone trying to finance a recycling plant, that uncertainty is the real obstacle: capacity has to be built for a 2030s peak whose size and timing are still unknown. Recycling a module is a sequence of separations, and each step exists because the previous one left something mixed together. Every step costs energy, reagents, or both, and each one eats into a margin that is already thin. It also explains a gap that confuses a lot of coverage. Mass recovery rates of 85 to 95 percent are routinely quoted, and some operators claim more than 99 percent, yet a line can hit those numbers while still losing nearly all of the module’s monetary value, because the materials that are easiest to recover in bulk are also the cheapest. Weight and worth are different measurements. One manufacturer has built the opposite model. First Solar, which makes thin-film cadmium telluride modules rather than silicon ones, has run a closed-loop process since 2005 and says it recovers more than 90 percent of module materials for reuse. The company states that a single kilogram of its semiconductor material can be recycled 41 times, which it equates to more than 1,200 years of use. The difference is that its process targets the semiconductor, not just the bulk. Almost every serious analysis of photovoltaic recycling reaches the same conclusion: the technology is not the bottleneck. The economics are. IRENA’s 2026 report identifies extended producer responsibility as the proven mechanism for resolving them. Under EPR rules, companies that place panels on the market carry the financial and practical responsibility for taking them back and treating them at end of life. That turns recycling from an optional cost into a designed-in one, and it gives recyclers the predictable, high-volume, single-chemistry feedstock that makes building a dedicated line worthwhile. Europe’s rules are the clearest working example, because they create collection volumes rather than leaving recovery to chance. The United States is further behind. Washington State passed the only solar-specific EPR law in 2017 and updated its implementation requirements in 2025. New Jersey passed mandatory recycling legislation in January 2026 but deliberately stopped short of EPR, leaving the cost with consumers rather than manufacturers. There is no federal framework, and the EPA’s effort to reclassify end-of-life panels as universal waste has slipped past its original target date. Landfill bans push from the other direction. When disposal is cheap and legal, recovered material struggles to compete with it. For a sense of how far the logic already extends, Australia’s first dedicated solar panel recycling facility began operating back in 2021, well before the bulk of the waste wave arrived. Kwong’s conclusion mirrors the same point from the opposite side: without EPR mandates, landfill restrictions or public subsidies, mainstream crystalline silicon recycling stays hard to justify. The panel is not the problem. The price of throwing it away is. For a household with a few decommissioned panels, the honest answer is less than the advertising suggests. The value concentrated in silver and silicon is real, but it only exists at industrial scale. A single panel handed to a recycler is a logistics cost rather than a commodity. Most owners should expect to pay a fee, not receive one, and that fee swings widely depending on where they live and how far the nearest specialist facility is. Before you decide what to do with a panel, it helps to work out which situation you are actually in: Landfilling a repairable panel is still rarely the best outcome. Modules still performing within their warranted output, which for most panels means at least 80 percent of rated power after 25 years, often retain resale value for off-grid, agricultural or hobby use, which delays the disposal problem and keeps working hardware in service. When a panel is genuinely finished, a dedicated recycler remains preferable to a general waste stream, because the glass, aluminium and remaining metals can at least be captured. Recovering precious metals from electronic waste is a maturing field, and panels are starting to be treated as part of it rather than as construction debris. Crystalline silicon accounts for roughly 95 percent of the global installed base, which has allowed recyclers to design around a single dominant chemistry. That advantage is temporary. Tandem and perovskite-containing designs are moving toward commercial production, and they stack different materials together in pursuit of higher efficiency. A line built to separate silicon, silver, glass and aluminium will not automatically know what to do with a stack that includes new absorber layers. Whether the industry standardises recovery processes early enough to avoid a second, more complicated waste stream is an open question. It will be settled by how the next generation of modules is designed, not by how today’s are dismantled. Barely, as individual units. A panel’s scrap value comes from its silver, silicon, aluminium and glass, but recovering those profitably depends on volume, purity and low processing costs. Many scrap dealers will not accept panels at all, and those that do tend to treat them as a handling cost rather than a commodity. Sometimes, but usually by selling them for reuse rather than recycling. Panels still producing close to their rated output have resale value for off-grid and agricultural applications. Panels that no longer work generally cost money to dispose of rather than generating any. Not much yet, on materials alone. Recycling a utility-scale module costs $15 to $45 in the United States, while landfilling it costs $1 to $5. Recovering silver and high-purity silicon changes that arithmetic, but researchers project those routes reaching commercial viability only in the 2030s, and only where policy support exists. It is an installation rule, not a recycling one. In many jurisdictions, rooftop arrays covering more than about a third of a roof’s plan-view area must meet extra fire-safety requirements, such as wider firefighter pathways and larger setbacks from the ridge. The rule exists to keep roofs accessible and ventilated in an emergency, and it is enforced locally rather than federally. The same phrase also circulates informally in the trade for a rough guideline about mixing panels of different wattages, which is a separate idea. For a utility-scale module in the United States, processing runs about $15 to $45, against $1 to $5 to landfill the same unit. Households usually face a per-panel fee plus transport, and the figure varies sharply by region because it depends on how far the nearest specialist facility is and whether local rules restrict disposal. Start with the company that installed the system, since many installers and manufacturers run take-back programmes, particularly for panels still under warranty. National and state recycling directories list specialist photovoltaic processors, and a growing number of general e-waste facilities now accept modules alongside other electronic equipment. The paradox of solar panel recycling is that the industry already knows how to do it. Delamination works. Silver can be recovered. Silicon can be purified back to wafer quality. What has not happened is the alignment of incentives that would make any of it pay at the scale the coming waste wave demands. Until disposal costs more than recovery, or until producers are required to take back what they sold, the most valuable 0.03 percent of every retired panel will keep going to landfill along with the glass around it. The fix is a price signal, not a breakthrough. Share post: Popular
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12 states have passed bills to authorize small solar systems. Solar energy panels hang from a residential apartment balcony in Erfurt, Germany. Balcony solar systems have become popular in Germany, and some state lawmakers believe the technology has huge potential in the United States. (Photo by Sean Gallup/Getty Images) Over the past year and a half, a dozen states have embraced a new vision for solar power: small, cheap panels that can be hung from a balcony or porch, be plugged into a standard wall outlet and take a dent out of residents’ utility bills. These systems, known as balcony solar or plug-in solar, are attractive because they can be installed without permits, contractors or large investments. They can allow renters to tap into clean electricity. Lawmakers say the systems can help at a time when residents’ power bills are skyrocketing and utilities are struggling to keep pace with demand. They also can be paired with a battery, which can provide backup power during area outages. Backers see a future in which solar panels deployed across millions of balconies, porches and yards could ease strain on the electrical grid and save residents hundreds of dollars each year on their power bills. Twelve states — Republican and Democratic alike — have recently passed bills authorizing residents to install such systems. Nine have been signed into law, while three are awaiting signatures from a governor. But for most Americans, even some in states that have passed laws, the systems still sit in a legal gray area. That’s because the “plug and play” simplicity that creates balcony solar’s appeal might not yet work safely with most household electrical systems, experts and utilities say. Work is underway to develop industry standards for such products, and advocates agree that such guidelines are necessary to draw manufacturers to the U.S. market. Backers say that plug-in solar systems have a long track record of operating safely in Germany and other countries, and argue that it’s imperative for the standards to allow for products that do not require a permit, home upgrades or a certified electrician to install. Meanwhile, power utilities haven’t strongly opposed the bills, though some have expressed concerns that unregistered systems could affect power flows or endanger line workers. For all the legislative action to boost balcony solar, advocates say the market won’t take off until safety groups give the all-clear for systems that don’t require red tape or electrical upgrades. The recent burst of balcony solar bills kicked off in Utah. Republican state Rep. Ray Ward read an article about the balcony solar boom in Germany, where the devices have surged in popularity and are widely available in stores such as IKEA. In Germany, more than 1 million balcony solar systems have been installed across the country, providing more than 2 gigawatts of power — the equivalent of a large power plant. “I thought, ‘How come I cannot do that in Utah and in the U.S.?’” Ward said. In Utah, as in many states, putting any amount of power onto the grid requires a contract with a utility, an impossible barrier for the average homeowner. Ward’s bill removes that requirement for solar panels up to 1,200 watts, roughly the amount of power used by a hair dryer. The bill passed unanimously through both houses of the Utah legislature last year, and Ward has balcony solar at his home. But the law also requires systems to meet National Electrical Code and Underwriters Laboratories certification standards, guidelines that are still in development. “The safety standards don’t exist, even though the products are plainly safe,” Ward said. “There is a way to make it safe, as Germany has shown, and we’ve just got to get safety standards in place here.” Since Utah’s bill became law, state lawmakers across the country have drafted similar bills. Many of the bills also prevent landlords and homeowners associations from restricting balcony solar. And many also seek to establish safety guidelines for the technology. “These things are just easy, simple, affordable, permitless ways to generate your own electricity — in whatever your living arrangement is — that enables everyone to contribute to reducing energy consumption in our country,” said Virginia state Sen. Scott Surovell, a Democrat. His bill drew bipartisan support and was signed into law in April. In New York, a bill passed in May awaits action by Democratic Gov. Kathy Hochul. Relief from energy bills unlikely as utilities request billions in rate hikes
“These solar panels could help you save 10% of your electricity bill each month, which is significant considering how much costs are going up,” said New York state Sen. Liz Krueger, a Democrat who sponsored the balcony solar bill. “In New York city, a huge percentage of us are renters, and up until now there’s been no way for us to participate in green energy or energy lowering projects.” Krueger said Hochul may ask for some small technical changes, which lawmakers are prepared to adopt. Colorado enacted a new law in May. “With power prices going up, people are wanting to find a way to be able to participate and have some control over their own energy,” said Colorado state Sen. Cathy Kipp, a Democrat who sponsored the measure. “As more states adopt it, it will drive down costs, which will further increase adoption.” Connecticut, Maine, Maryland, New Hampshire, New Jersey and Vermont have also enacted balcony solar laws since 2025. Bills in California and Massachusetts have passed and sit on the governor’s desk. The state measures have been supported by Bright Saver, a nonprofit advocacy group that envisions 60 million balcony solar panels deployed across the country by 2035. Cora Stryker, the group’s co-founder, said several lawmakers told her they’d never seen a measure go from an idea to a law so quickly. But the success of those new laws, she said, hinges on the development of safety standards that allow balcony solar systems to be simple “plug and play” devices. “The widespread adoption we’re talking about will only happen when we get out of this legal gray area and every American can feel confident that they can plug it in without contacting their utility,” she said. Bright Saver sells balcony solar systems at cost, offering 180-watt panels for $285 and 360-watt panels for $414. But it cannot sell to customers in some states that have passed solar legislation, because products don’t yet exist that can meet their safety certifications. Other companies sell kits online, but experts say it’s hard for customers to know if those devices meet safety thresholds. While backers do not have estimates for nationwide adoption totals, they say the numbers will remain low until balcony solar systems are widely available at popular retailers. Underwriters Laboratories, a global safety science company, recently issued certification standards that would require residents to modify circuits before plugging in devices — a hurdle that advocates fear could slow the adoption of balcony solar. The main concern, experts say, is that power outlets in U.S. homes are not designed to carry power in two directions. Sending electricity back into the system could bypass circuit protection devices, overloading wires and creating fire or shock hazards. “Some of these (bills and laws) are a little ahead of their time,” said Nadav Enbar, program manager at the nonprofit Electric Power Research Institute. “There isn’t yet a product that can meet the letter of the law.” Some of the state laws call for products to achieve certification from Underwriters Laboratories. The company issued its certification program, known as an outline of investigation, in January. States fast-track wind, solar permits and contracts to beat Trump’s deadline
While those guidelines are still working through a committee process — which could take a year or more — to be finalized as a permanent standard, the company says they still count as official certification for manufacturers seeking to comply with state laws. The current certification requires residents to modify circuits in their home to safely receive electricity. Electrical experts said it’s possible that manufacturers will eventually be able to develop balcony solar systems that address the circuit overload concerns with onboard technology. “Could there in the future be another way to address these problems? Sure,” said Joe Bablo, principal engineering manager with UL Solutions, one of the three organizations that makes up Underwriters Laboratories. “Will the standard adapt to that? Of course.” The certification also requires the use of a proprietary connector that ensures the blades will not continue carrying electricity after being unplugged from the wall. The National Electric Code offers another possibility for a widely accepted standard that manufacturers could follow, but new revisions to the code will not be issued until 2029. Some utilities have also raised concerns about large-scale adoption affecting local power flows, or solar systems feeding power into the grid during blackouts and putting line workers at risk. Utility leaders have called for a program that requires balcony solar users to register or notify utilities when installing their devices. “We just need people to let us know what they’re plugging in, so we can track anything that feeds back into the grid and can be a danger to line workers,” said David Eisenhauer, spokesperson for the California power utility Southern California Edison. The utility initially opposed the California bill, but adopted a neutral position after language was added to allow utilities to require registration of balcony solar units. Stateline reporter Alex Brown can be reached at [email protected]. YOU MAKE OUR WORK POSSIBLE. by Alex Brown, Stateline September 30, 2026 by Alex Brown, Stateline September 30, 2026 Over the past year and a half, a dozen states have embraced a new vision for solar power: small, cheap panels that can be hung from a balcony or porch, be plugged into a standard wall outlet and take a dent out of residents’ utility bills. These systems, known as balcony solar or plug-in solar, are attractive because they can be installed without permits, contractors or large investments. They can allow renters to tap into clean electricity. Lawmakers say the systems can help at a time when residents’ power bills are skyrocketing and utilities are struggling to keep pace with demand. They also can be paired with a battery, which can provide backup power during area outages. Backers see a future in which solar panels deployed across millions of balconies, porches and yards could ease strain on the electrical grid and save residents hundreds of dollars each year on their power bills. Twelve states — Republican and Democratic alike — have recently passed bills authorizing residents to install such systems. Nine have been signed into law, while three are awaiting signatures from a governor. But for most Americans, even some in states that have passed laws, the systems still sit in a legal gray area. That’s because the “plug and play” simplicity that creates balcony solar’s appeal might not yet work safely with most household electrical systems, experts and utilities say. Work is underway to develop industry standards for such products, and advocates agree that such guidelines are necessary to draw manufacturers to the U.S. market. Backers say that plug-in solar systems have a long track record of operating safely in Germany and other countries, and argue that it’s imperative for the standards to allow for products that do not require a permit, home upgrades or a certified electrician to install. Meanwhile, power utilities haven’t strongly opposed the bills, though some have expressed concerns that unregistered systems could affect power flows or endanger line workers. For all the legislative action to boost balcony solar, advocates say the market won’t take off until safety groups give the all-clear for systems that don’t require red tape or electrical upgrades. The recent burst of balcony solar bills kicked off in Utah. Republican state Rep. Ray Ward read an article about the balcony solar boom in Germany, where the devices have surged in popularity and are widely available in stores such as IKEA. In Germany, more than 1 million balcony solar systems have been installed across the country, providing more than 2 gigawatts of power — the equivalent of a large power plant. “I thought, ‘How come I cannot do that in Utah and in the U.S.?’” Ward said. In Utah, as in many states, putting any amount of power onto the grid requires a contract with a utility, an impossible barrier for the average homeowner. Ward’s bill removes that requirement for solar panels up to 1,200 watts, roughly the amount of power used by a hair dryer. The bill passed unanimously through both houses of the Utah legislature last year, and Ward has balcony solar at his home. But the law also requires systems to meet National Electrical Code and Underwriters Laboratories certification standards, guidelines that are still in development. “The safety standards don’t exist, even though the products are plainly safe,” Ward said. “There is a way to make it safe, as Germany has shown, and we’ve just got to get safety standards in place here.” Since Utah’s bill became law, state lawmakers across the country have drafted similar bills. Many of the bills also prevent landlords and homeowners associations from restricting balcony solar. And many also seek to establish safety guidelines for the technology. “These things are just easy, simple, affordable, permitless ways to generate your own electricity — in whatever your living arrangement is — that enables everyone to contribute to reducing energy consumption in our country,” said Virginia state Sen. Scott Surovell, a Democrat. His bill drew bipartisan support and was signed into law in April. In New York, a bill passed in May awaits action by Democratic Gov. Kathy Hochul. Relief from energy bills unlikely as utilities request billions in rate hikes
“These solar panels could help you save 10% of your electricity bill each month, which is significant considering how much costs are going up,” said New York state Sen. Liz Krueger, a Democrat who sponsored the balcony solar bill. “In New York city, a huge percentage of us are renters, and up until now there’s been no way for us to participate in green energy or energy lowering projects.” Krueger said Hochul may ask for some small technical changes, which lawmakers are prepared to adopt. Colorado enacted a new law in May. “With power prices going up, people are wanting to find a way to be able to participate and have some control over their own energy,” said Colorado state Sen. Cathy Kipp, a Democrat who sponsored the measure. “As more states adopt it, it will drive down costs, which will further increase adoption.” Connecticut, Maine, Maryland, New Hampshire, New Jersey and Vermont have also enacted balcony solar laws since 2025. Bills in California and Massachusetts have passed and sit on the governor’s desk. The state measures have been supported by Bright Saver, a nonprofit advocacy group that envisions 60 million balcony solar panels deployed across the country by 2035. Cora Stryker, the group’s co-founder, said several lawmakers told her they’d never seen a measure go from an idea to a law so quickly. But the success of those new laws, she said, hinges on the development of safety standards that allow balcony solar systems to be simple “plug and play” devices. “The widespread adoption we’re talking about will only happen when we get out of this legal gray area and every American can feel confident that they can plug it in without contacting their utility,” she said. Bright Saver sells balcony solar systems at cost, offering 180-watt panels for $285 and 360-watt panels for $414. But it cannot sell to customers in some states that have passed solar legislation, because products don’t yet exist that can meet their safety certifications. Other companies sell kits online, but experts say it’s hard for customers to know if those devices meet safety thresholds. While backers do not have estimates for nationwide adoption totals, they say the numbers will remain low until balcony solar systems are widely available at popular retailers. Underwriters Laboratories, a global safety science company, recently issued certification standards that would require residents to modify circuits before plugging in devices — a hurdle that advocates fear could slow the adoption of balcony solar. The main concern, experts say, is that power outlets in U.S. homes are not designed to carry power in two directions. Sending electricity back into the system could bypass circuit protection devices, overloading wires and creating fire or shock hazards. “Some of these (bills and laws) are a little ahead of their time,” said Nadav Enbar, program manager at the nonprofit Electric Power Research Institute. “There isn’t yet a product that can meet the letter of the law.” Some of the state laws call for products to achieve certification from Underwriters Laboratories. The company issued its certification program, known as an outline of investigation, in January. States fast-track wind, solar permits and contracts to beat Trump’s deadline
Independent power producer (IPP) Rezolv Energy has secured a €561 million (US$637 million) financing for its 1.3GWp Dama Solar project in Romania. Located in Arad County, western Romania, it is the largest onshore renewable energy project in the European Union and will begin construction imminently. Get Premium Subscription Commercial operation at the 1.3GW Dama Solar project is expected to begin in the second half of 2028. The solar park will cover more than 1,000 hectares and include an 82-hectare nature reserve. The IPP, which is backed by renewable energy infrastructure investor Actis, secured the final legal approval required to begin construction of the Dama solar project last month. Structured as a green loan, the €561 million financing was underpinned by an anchor investment by the European Investment Bank (EIB), benefitting from an Invest EU guarantee, which has been provided by a consortium of 14 lenders, comprising 10 commercial banks – Erste Group Bank, UniCredit Bank, Banca Comercială Intesa Sanpaolo Romania, Société Générale, OTP Bank, Československá obchodní banka (ČSOB), Raiffeisen Bank S.A., Raiffeisenlandesbank Niederösterreich-Wien, Piraeus Bank and Siemens Bank – and three additional development finance institutions: European Bank for Reconstruction and Development (EBRD), International Finance Corporation (IFC) and Black Sea Trade and Development Bank (BSTDB). The financing for the Dama Solar project is the largest the IPP has secured to date, both in terms of the amount and the number of lenders involved. It surpasses the €291 million secured for Phase 1 of a wind farm, the €331 million for Phase 2 of the same project and the €90 million in debt financing secured for the 225MW St. George solar park in Bulgaria. The St. George project began commercial operations in May of this year. Jaroslava Korpanec, head of Central and Eastern Europe, Infrastructure at Actis, said: “We believe this financing package, backed by 14 lenders, reflects the depth of investor confidence in Romania’s renewable energy sector and in Rezolv Energy in particular. Dama Solar will become the EU’s largest onshore renewable energy project, financed under a green loan structure that has earned Moody’s highest possible sustainability rating.” Moreover, Rezolv Energy previously secured two Contracts for Difference (CfDs) for the Dama Solar project in Romania’s second CfD auction covering 520MW of the project’s capacity. The IPP has also secured a corporate power purchase agreement with an undisclosed offtaker. The Dama Solar project represents nearly half of the 2.8GW portfolio of large-scale renewable energy projects that Rezolv Energy is developing in Romania and Bulgaria. PV Tech publisher Informa will be organising the sixth edition of SolarPlus Central & Eastern Europe in Warsaw, Poland, on 24-25 November 2026. Central & Eastern Europe has emerged as one of the most dynamic solar and energy storage markets, marking the evolution of the event from Large Scale Solar CEE to SolarPlus CEE, and addressing the hybridisation of the market throughout the two days. For more details regarding the event’s programme and how to register, click the link above.
In the United States, 93% of new power generation capacity this year is expected to come from solar and wind generation and energy storage systems. Leah Stokes, an associate professor of environmental policy at the University of California, Santa Barbara, wrote about this in an opinion piece for Live Science. In her assessment, the development of renewable energy is determined primarily by costs: more than 90% of new renewable energy projects are already cheaper than new fossil fuel facilities. Stokes argues that tariffs on solar panels and batteries raise costs for Americans but will not stop the overall decline in the cost of clean energy. The author notes that since 2015, most new energy facilities in the United States have belonged to clean generation. At the same time, fossil fuels currently generate 57% of the country’s electricity, while clean sources account for 43%. Coal provides approximately one-sixth of US electricity generation. According to data cited in the opinion piece, keeping 99% of US coal power plants operating is more expensive than replacing them with new solar and wind capacity and energy storage systems. More current news is available on the UA.News Telegram channel Telegram. Stokes also mentioned the J.H. Campbell power plant in Michigan, which the Donald Trump administration ordered to remain open after its planned retirement. According to her, this decision cost consumers $600,000 a day, and on September 11 a federal court rejected the relevant order. Demand for electricity is growing, including due to the development of artificial intelligence, data centers, and electrification. At the same time, more than three-quarters of proposed gas power plants for data centers are at an early stage of implementation, while deliveries of gas turbines are being delayed into the 2030s, Stokes writes. In her assessment, solar power plants and battery systems can be built in less than two years. The author also points to opportunities for states and cities to accelerate the transition: simplify the installation of plug-in solar panels, encourage electricity consumption during hours of excess solar generation, and introduce flexible electrical systems in buildings. Use of materials from the websites https://ua.news/ is permitted only if a reference (or, for online publications, a hyperlink) to UA.NEWS is included no later than the third paragraph. Use of materials is permitted only upon receipt of written permission from the UA.NEWS editorial board and the mandatory placement of a direct hyperlink to the original publication https://ua.news/ in the first paragraph of the material, which must be open to indexing by search engines. Materials marked with the “Advertisement” label are promotional and are published as advertisements. The editorial board may not share the views promoted therein. The editorial staff is not responsible for the facts and opinions published in advertising materials. In accordance with current Ukrainian legislation, the advertiser is responsible for the content of the advertisement. Materials in the “Blogs” section represent the personal opinion of the blog author; the editorial staff may not share the author’s views. Copyright infringement is prosecuted in accordance with the current legislation of Ukraine and the norms of international law. The online media outlet UA.NEWS serves only an audience aged 21 and older. Online media entity; media identifier – R40-05225. LLC “NEWS FLASH INFORMATION AGENCY.” All rights reserved.
Non-profit. Reader-funded. Independent. Anant Ambani leads Reliance’s clean-energy business. By our estimate, one of his projects alone could cut about 29 million tons of CO2 a year. New Delhi [India], September 29: Anant Ambani works in oil. His big bet is on sunshine. Reliance Industries controls the world’s largest oil-refining complex. But Anant Ambani, who is leading the clean-energy business, wants to focus on something different from what has already been established.
Anant Ambani is executive director of Reliance Industries. Since 2022, he has been working on new-energy businesses like solar power, batteries, and green hydrogen. His main goal is to achieve Net-zero carbon by 2035.
He summed up his whole idea and put it under one line at Reliance’s annual meeting in June 2026: “The world built its old energy on Middle Eastern oil. Now, the world will build its new energy on Indian sunshine.”
The sunshine looks like this in actual numbers. A solar project in Kutch is bigger than London, and it can power 3% of India
A bigger part of Reliance’s clean-energy plans is happening in Kutch, Gujarat.
Waaree Renewable Technologies Ltd (WRTL) has received a revised scope of work under an existing engineering, procurement and construction (EPC) contract for a 2,012.47 MWp ground-mounted solar PV project. The project was awarded by a domestic entity engaged in the development and implementation of renewable energy projects. The revised scope increases the value of the commercial order by INR 14.79 crore, while all the terms and conditions of the contract remain same, according to the company. The project is scheduled for completion during the current fiscal year 2026-27. WRTL said the aggregate order size remains same at 2012.47 MWp as per the first disclosure submitted to the stock exchange on Nov. 27, 2024. The project was originally valued at around INR 1,233.48 crore, excluding taxes. 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 Join pv magazine for an expert session exploring quality, technology and the challenges of scaling India’s solar industry. The new issue of pv magazine Global is out now! Available in print and digital – get your copy today!
Nifty 50 Products Distribution Products Services Platform Tools & Calculators Stocks F&O Mutual Funds ETFs Research Pricing Resources Authored By HDFC SKY | Published at: Sep 30, 2026 03:08 PM IST Solarworld Energy Solutions has received a ₹78.75 crore purchase order for supplying 96,000 solar panels to a leading renewable energy player, while shares rise 2.01%. By signing up I certify terms, conditions & privacy policy Mumbai, September 30: Solarworld Energy Solutions has received a purchase order from a leading renewable energy player for the supply of 96,000 solar panels, with the order valued at ₹78.75 crore including GST. According to the exchange filing, the purchase order was received by ZNShine Solarworld Private Limited, a wholly owned subsidiary of Solarworld Energy Solutions. The order covers the supply of 96,000 G12R 625 Wp solar panels. The basic order value is ₹75 crore, while the total value including 5% GST comes to ₹78.75 crore. The unit price specified in the order is ₹7,812.50 per solar panel. The customer has been identified as a leading renewable energy player, while the company has classified the order as domestic. The Solarworld Energy share price stood at ₹131.57 as of 2:35:55 PM IST on September 30, 2026. The stock was up ₹2.59, or 2.01%, at the time. Shares gained momentum during the afternoon session and moved above the ₹131 level before trading at ₹131.57. The share price movement came a day after the company received the purchase order, with the disclosure stating that the event occurred on September 29, 2026. The purchase order involves G12R 625 Wp solar panels, with delivery to be carried out in accordance with the terms and conditions agreed with the customer. At 625 Wp per panel, the 96,000-panel order represents approximately 60 MW of module capacity. The order is part of the company’s solar manufacturing and supply business, with the panels intended for a leading player in the renewable energy sector. The company said the transaction is not a related-party transaction and that its promoter, promoter group and group companies have no interest in the customer. Solarworld Energy Solutions operates in the renewable energy space, with its business focused on solar power and related solutions. The latest purchase order adds to the company’s project and supply pipeline, with the subsidiary set to supply a sizeable volume of solar modules under the agreed commercial terms. The company has not disclosed the name of the customer in the exchange filing. Solarworld Energy Solutions has secured a purchase order for 96,000 G12R 625 Wp solar panels from a leading renewable energy player. The order carries a basic value of ₹75 crore and a total value of ₹78.75 crore including GST. The Solarworld Energy share price stood at ₹131.57 as of 2:35:55 PM IST on September 30, 2026, up ₹2.59 or 2.01%. Source: At HDFC SKY*, we take utmost care and due diligence in curating and presenting news and market-related content. However, inadvertent errors or omissions may occasionally occur. If you have any concerns, questions, or wish to point out any discrepancies in our content, please feel free to write to us at content@hdfcsec.com. Please Note: The information shared is intended solely for informational purposes and does not make any investment recommendations. HDFC SKY from HDFC Securities, one of most trusted trading platforms in India, has been recognized with the *Next-Gen Digi Content Awards 2025-26. 3 min read By signing up I certify terms, conditions & privacy policy Sector: Utilities Solarworld Energy Solutions Ltd. ₹131.73 By signing up I certify terms, conditions & privacy policy Attention To Investors Prevent unauthorised transactions in your account. 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Generally cloudy. Slight chance of a rain shower. High 16C. Winds N at 10 to 15 km/h.. Overcast. Slight chance of a rain shower. Low 11C. Winds light and variable. Updated: September 30, 2026 @ 6:24 am
The recent fire at the Sunbank solar farm in Summerside, which lasted more than two weeks, should be a wake-up call to those who collect their own power via solar panels on their property. The incident shows just how important it is to be ready for any kind of incident involving the panels. Javascript is required for you to be able to read premium content. Please enable it in your browser settings. {{description}} Email notifications are only sent once a day, and only if there are new matching items. Your comment has been submitted.
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SP Samhwa said on the 30th that it obtained a patent related to a heat-dissipating paint composition applicable to glass-steel structure building-integrated photovoltaics (BIPV) modules. The patent was pursued by SP Samhwa to secure technological competitiveness in response to the growing BIPV market driven by the government’s carbon-neutral policy and the expansion of mandatory zero energy building (ZEB) standards. The patented technology effectively lowers heat accumulated on the back of steel plates, improving power generation efficiency of photovoltaic modules as temperatures rise. BIPV modules combine building exterior materials with photovoltaic power generation functions, and because BIPV modules are attached directly to building facades, they tend to accumulate more heat than general ground-mounted photovoltaic modules. In particular, the G2S (Glass-to-Steel) structure made of glass and steel has higher structural stability than the conventional glass-backsheet structure, but has the limitation that heat on the back of the steel plate does not dissipate well, making it easy for the module temperature to rise. It is known that for photovoltaic modules, power generation efficiency decreases by about 3% for every 10°C increase in surface temperature, so power loss becomes pronounced in hot summer conditions. The heat-dissipating paint using the patented technology releases heat accumulated in BIPV modules in three stages: “thermal conduction,” which rapidly spreads heat delivered from the steel plate throughout the coating film; “thermal radiation,” which emits heat from the coating surface as infrared; and “convection,” which performs heat exchange with the surrounding air. SP Samhwa expects that, if commercialized, this technology will minimize the drop in power generation efficiency due to temperature rise in G2S-structure BIPV modules and slow the rate of module degradation, contributing to longer product lifespans. Along with obtaining the patent, SP Samhwa has completed lab-scale performance verification and plans to define the commercialization timeline after demonstration testing. An SP Samhwa official said, “This patent is a new technology that can improve the drop in power generation efficiency caused by rising temperatures, a known issue for BIPV modules,” adding, “We will expedite commercialization through demonstration testing and expand application to a variety of BIPV product lines.”
Durham University’s 22 September 2026 project announcement identifies £5.3 million in ARIA funding for LIVINGSTON, a collaboration with Scalable Laser and the University of Glasgow to develop laser power beaming for high-altitude aircraft. The proposed system would turn electricity into laser light on the ground, transmit it through the atmosphere and convert it back into electricity aboard an aircraft. The announcement describes technology to be developed, not an aircraft already flying on beamed power. ARIA’s funded-project register lists LIVINGSTON as active enabling-technology research led by Scalable Laser’s Richard Hogg. It places systems integration and testing in a separate strand, whose broader goal is continuous power delivery to a payload while an aircraft keeps station. An active listing establishes that LIVINGSTON is funded research; it does not establish that the proposed power link works in flight. The energy chain begins at an electrical supply feeding a ground-based flat-panel laser emitter. The emitter converts some input electricity into light, and ground-station optics direct that light toward a photovoltaic receiver carried by the aircraft. The receiver converts the light it captures into electrical power. Keeping the aircraft aloft depends on enough usable electricity reaching its loads, not merely on a bright beam leaving the ground. The Scalable Laser project account assigns the emitter to Scalable Laser, the photovoltaic converter to Glasgow and the beam-directing optics to Durham; it describes a proposed link to a platform up to 25 km away. Glasgow’s receiver is intended to match the laser’s wavelength, so its conversion performance will depend on the light that actually arrives. Durham’s optics must deliver that light to the receiver despite the distance and changing air between them. Moving the energy source to the ground is the project’s appeal: an aircraft could draw power without carrying all of the fuel, battery capacity or solar collection area needed for a long mission. That possibility comes with a new dependency. The aircraft would need a suitable ground station and an optical path capable of supplying power when it is required. The project descriptions do not yet show how those dependencies would be managed during sustained flight. The beam has to follow an aircraft rather than illuminate a fixed target. A tightly directed beam can put more light onto a relatively small receiver, but a pointing error can send it outside the collecting area. The challenge grows with distance: a small change in the beam’s direction at the ground station can become a substantial displacement where the aircraft is flying. Tracking the aircraft’s location addresses only part of that problem. Heat and atmospheric turbulence can distort a beam as it travels. The proposed optical arrangement uses a reference beacon on the airborne platform to measure distortion and a rapidly adjustable mirror at the ground station to correct the outgoing light. The correction must work while the aircraft moves and the conditions along the path change; a well-aimed beam at one instant does not guarantee a stable power supply. Weather presents a separate obstacle. Cloud, haze or precipitation can reduce the light reaching the receiver even when tracking is accurate. A practical system would have to establish how often a usable path is available and what happens when delivery falls below the aircraft’s demand. The public descriptions do not quantify that availability or specify how long an interruption the aircraft could tolerate. Performance must be measured across the whole chain: electrical input at the ground station, conversion into laser light, losses in the optics and atmosphere, the fraction captured by the airborne receiver, and conversion back into electricity. Each stage reduces the power available at the next. A strong result for the laser or photovoltaic converter alone would therefore say little about the electricity an aircraft could use. Receiver area creates a trade-off. A larger surface could collect more light when the beam spreads or shifts, but the aircraft must carry its mass and accommodate its shape. The ground station also needs electrical supply, cooling and control equipment. Assessing the concept means comparing sustained electrical output aboard the aircraft with the ground input and the hardware needed at both ends, under changing atmospheric conditions. The cited project descriptions provide no measured end-to-end efficiency for LIVINGSTON and no measured electrical output from an aircraft-mounted receiver. They also do not report how delivered power varies with pointing error or weather. Those measurements would show whether component improvements combine into a useful airborne supply; until they exist, continuous operation remains an objective rather than a demonstrated capability. LIVINGSTON has a funded collaboration, a division of engineering work and a proposed way to correct atmospheric distortion. The available material does not report an integrated ground-to-air flight test or an aircraft kept aloft continuously by its beam. Its place in ARIA’s enabling-technology strand is consistent with that stage of development. An integrated demonstration would need to show the emitter, optics and receiver operating together over a real atmospheric path while the receiver moves. It would need sustained measurements of ground input and airborne electrical output, including periods when tracking or visibility deteriorates. A flight system would also need to show how the beam is controlled if alignment is lost or other aircraft enter the relevant airspace; the project announcements present no such validation result. The confirmed development is the effort to build a ground-to-air power link. The next evidence that could change the story is measured electrical delivery to an airborne receiver, followed by proof that delivery can be maintained long enough to support flight. For now, keeping aircraft aloft with ground power is LIVINGSTON’s aim, not its reported achievement. Also read: Get the latest Web3, AI, and crypto news delivered straight to your inbox. QUASA brings together technology media, digital-product discovery, rewards, work opportunities and selected uses of QUA in one connected ecosystem.
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