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Posted August 21, 2026 01:28pm by Stan Maddux
(La Porte County, IN) – A company is going to court over its plans for a solar farm being rejected by the La Porte County Board of Zoning Appeals last month.
 
In its lawsuit, Hoosier Solar says the plans met all of the requirements but the BZA failed to list its reasons for turning down its request for a special exception to the current agricultural zoning by a 3 to 2 vote.
 
The company also argues the process was biased from having a board member and a county commissioner reveal their opposition to the plans before the vote.
 
In the lawsuit, Hoosier Solar said there was reason to believe BZA member Jeff Baltes has funded and participated in the distribution of signage opposing solar projects across the county.  The lawsuit claims Baltes had a sign posted at his home reading “No Industrial Solar Plants on Farmland” as recently as April 23.
 
The commissioners replaced Baltes with Lefeber as an alternate member of the BZA appointed to strictly vote on the special exception request.  But, the lawsuit alleges Lefeber attended a BZA meeting in May to speak against the request he was now empowered to vote on, a violation of state law that requires a neutral and unbiased fact finder in BZA –quasi-judicial proceedings.
 
The lawsuit also points to publicly made remarks from Holifield like one that describes Hoosier Solar as “outside carpet baggers” wanting a solar farm only to possibly obtain a federal tax credit, statements the company called false and disparaging to again try and illustrate how the process was not impartial and fair as required.   
 
The lawsuit is asking the court to order the BZA to approve the plans.
 
The proposed solar farm would be on about 300 acres of farmland in the eastern part of the county near the St. Joseph County line.
 
In response, Holifield said the best location for the solar farm is the mostly secluded Kingsbury Industrial Park.  He also defended his prior remarks against solar farms on farmland, saying he has a right to freedom of speech.
 
“I got my opinions, too, and we’re not allowed to have opinions?  I will stand and I will testify. I’ll do whatever I have to do to prevent this from happening,” he said.
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The global solar PV manufacturing landscape is evolving rapidly, with technology roadmaps diverging across regions. While China advances beyond first-generation TOPCon into back-contact (BC) and hybrid architectures, hubs like India, Europe, and North America are balancing TOPCon expansion, HJT, and tandem concepts.
To help you navigate these shifts, TaiyangNews is hosting the Cell & Module Production Equipment & Processing Materials Conference, bringing together top equipment manufacturers, material suppliers, and PV makers.
At the conference, Josua Stückelberger, Director of Technology – International Business Unit at Laplace, will be speaking on the topic: Beyond Equipment: Building the Next Generation of Solar Manufacturing.
The virtual conference is scheduled from 09:30 to 13:00 CEST on Tuesday, August 25, 2026. Register for free here.
A consortium of local investment and industrial development institutions, including Jiangsu Environmental Protection Group (JSEP) and the Wuxi City government in Jiangsu Province, has launched the RMB 1 billion Wuxi Xichuang Suhuan Green and Low-Carbon Strategic Emerging Industries Venture Capital Fund. The fund targets energy efficiency, environmental protection, and other dual-carbon sectors, with perovskite technology identified as a priority investment area. It plans to use an ‘industry plus capital plus industrial park’ model to support the commercialization and industrial clustering of next-generation PV technologies.
Wuxi is already home to perovskite companies including UtmoLight, Perovs, and Yongjia Solar. Notably, UtmoLight is investing in a 1 GW perovskite PV production line and innovation center in the city.
PV manufacturer BAJ Solar has signed restructuring investment agreements with multiple financial investors, including Yunnan International Trust Co., Ltd. As part of the agreements, the investors plan to subscribe for an aggregate of 144.5 million shares generated through a capital reserve conversion, for a total investment of about RMB 378 million.
BAJ Solar expects a net loss of RMB 225 million to RMB 335 million in the first half of 2026, citing production suspensions at its PV subsidiaries, fixed costs related to assets and leases, and debt-related risks.
The company previously brought in Meinian Onehealth as an industrial restructuring investor. If the restructuring is successfully implemented, Meinian Onehealth will become BAJ Solar’s controlling shareholder (see China Solar PV News Snippets).
Energy storage solution provider SERMATEC has commissioned a 150 MW/300 MWh PV-plus-storage project in Shihezi, Xinjiang. The project represents an investment of about RMB 200 million and comprises 30 sets of 5 MW/10 MWh lithium iron phosphate battery systems designed for two-hour charging and discharging.
The facility is designed to provide millisecond-level power regulation and participate in primary and secondary frequency regulation, as well as other ancillary services. Once commissioned, the project is expected to generate 78.66 million kWh annually and produce annual revenue of about RMB 28 million through peak-valley arbitrage, ancillary-service compensation, and the recovery of curtailed solar power.
Battery maker EVE Energy reported first-half operating revenue of RMB 45.69 billion, up 62.20% year-on-year, while net profit rose 105.66% to RMB 3.30 billion. Adjusted net profit increased 111.89% to RMB 2.45 billion.
The company shipped 35.76 GWh of power batteries during the period, up 66.47%, and 44.46 GWh of energy storage batteries, up 54.88%. EVE Energy said shipments for commercial vehicles and its large cylindrical battery business continued to grow rapidly.
The company also claims to be the first globally to mass-produce 600 Ah-plus large prismatic lithium iron phosphate energy storage cells. It plans to continue developing larger-capacity cells for highly integrated energy storage systems.
EVE Energy was recently ranked among the top 5 energy storage cell suppliers by InfoLink Consulting (see China Solar PV News Snippets).
TaiyangNews 2024

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According to the latest IndexBox report on the global Flashing and Weathering Membrane market, the market enters 2026 with broader demand fundamentals, more disciplined procurement behavior, and a more regionally diversified supply architecture.
The global flashing and weathering membrane market is entering a period of sustained expansion, with demand projected to rise at a compound annual growth rate of 6-9% between 2026 and 2035. This growth is underpinned by the rapid build-out of solar photovoltaic installations, which now account for an estimated 55-65% of global membrane consumption by volume. As utility-scale and distributed solar projects multiply across Asia-Pacific, North America, and Europe, the need for durable, weather-resistant flashing and weathering membranes continues to intensify. At the same time, stricter building envelope waterproofing requirements, driven by updated energy codes and climate resilience standards, are pushing commercial and residential construction toward higher-performance membrane solutions. The market is also witnessing a structural shift toward premium-grade, high-durability formulations, including silicone-based and advanced polyolefin membranes, which represent 30-40% of market value despite a smaller volume share. This trend reflects a broader industry move toward lifecycle cost optimization, longer warranty periods, and reduced maintenance frequency. Digital specification platforms and Building Information Modeling (BIM) integration are becoming standard workflow tools, enabling contractors and procurement teams to pre-qualify membrane products by performance attributes, compliance status, and supply lead time. However, input cost volatility for polymer feedstocks, supplier qualification bottlenecks, and trade documentation complexity remain key challenges. This report provides a comprehensive analysis of market size, demand structure, supply capability, trade flows, pricing, and competitive landscape, offering a data-driven view of the market’s trajectory to 2035.
The baseline scenario for the flashing and weathering membrane market points to steady growth through 2035, with global consumption expanding at a compound annual rate of 6-9%. The market index, with 2025 as the base year (100), is projected to reach approximately 185 by 2035, reflecting a near-doubling of demand over the forecast period. This growth is anchored in the continued expansion of solar photovoltaic capacity, which remains the dominant demand driver. As governments worldwide commit to net-zero targets and renewable energy mandates, solar installations are expected to grow at a double-digit pace, directly boosting demand for flashing and weathering membranes used in solar mounting systems. In parallel, the commercial roofing retrofit market is gaining momentum, particularly in North America and Europe, where aging building stock and stricter energy efficiency regulations are driving the replacement of traditional flashing materials with advanced membrane systems. The industrial processing segment, including food and beverage facilities and chemical plants, is also contributing to demand growth, as hygienic design standards and chemical resistance requirements become more stringent. The market is characterized by a gradual shift toward premium products, with high-durability formulations capturing an increasing share of value. Supply-side dynamics are shaped by vertical integration among solar mounting system providers, who are internalizing membrane specification and procurement to reduce warranty coordination risks. However, the market faces headwinds from polymer feedstock price volatility, limited availability of dual-certified suppliers, and trade documentation complexity. Despite these challenges, the overall outlook remains positive, supported by favorabl
Solar mounting applications represent the largest and fastest-growing segment of the flashing and weathering membrane market, accounting for an estimated 60% of global demand by volume. The segment’s growth is directly tied to the global expansion of photovoltaic installations, both utility-scale and distributed. As solar farms and rooftop arrays proliferate, the need for reliable weatherproofing at panel mounting points, roof penetrations, and cable entry points becomes critical. Flashing and weathering membranes provide a durable barrier against moisture ingress, ensuring the long-term integrity of solar mounting systems. Through 2035, the segment is expected to maintain robust growth, supported by government renewable energy targets, declining solar panel costs, and technological advancements in mounting hardware. Demand-side indicators include annual solar capacity additions, project pipeline data, and the adoption of bifacial and tracking systems, which require more complex mounting and sealing solutions. Vertical integration among solar mounting system providers is reshaping procurement, with OEMs increasingly specifying membrane products to ensure compatibility and warranty coverage. The trend toward higher-efficiency panels and larger installation footprints further amplifies membrane demand per project. Current trend: Dominant and growing rapidly.
Major trends: Vertical integration of membrane specification by solar mounting OEMs, Growth in utility-scale solar farms requiring extensive flashing systems, Adoption of bifacial and tracking systems increasing sealing complexity, and Shift toward high-durability membranes for 25+ year service life.
Representative participants: Nextracker Inc, Array Technologies Inc, GameChange Solar, Solar FlexRack, and DPW Solar.
Industrial processing facilities, including food and beverage plants, chemical manufacturing sites, and pharmaceutical facilities, constitute a significant and stable demand segment for flashing and weathering membranes. These facilities require penetration sealing materials that meet stringent hygienic design standards and chemical resistance criteria. Membranes used in this segment must withstand exposure to cleaning agents, chemicals, and temperature variations while maintaining a watertight seal. The demand for food-grade and processing-aid compatible membranes is growing at an estimated 8-12% annually, as regulatory bodies like the FDA and EFSA tighten indirect-contact criteria. Through 2035, the segment is expected to grow steadily, supported by ongoing investments in industrial infrastructure, particularly in emerging markets. Demand-side indicators include industrial construction spending, food and beverage production volumes, and the adoption of hygienic design standards. The trend toward modular and prefabricated processing facilities is also influencing membrane requirements, as prefabricated components need reliable flashing at joints and connections. Major companies in this segment are focusing on developing membranes with documented compliance and enhanced durability to meet the evolving needs of industrial end-users. Current trend: Steady growth driven by hygienic and chemical resistance requirements.
Major trends: Growing demand for food-grade and FDA/EFSA-compliant membranes, Increased focus on chemical and heat resistance in processing environments, Adoption of modular construction in industrial facilities, and Rising investment in pharmaceutical and biotech manufacturing.
Representative participants: Sika AG, BASF SE, Dow Inc, GCP Applied Technologies, and Carlisle Companies Inc.
Commercial roofing retrofit projects represent a substantial and growing application for flashing and weathering membranes, particularly in mature markets like North America and Europe. Aging building stock, combined with stricter energy efficiency regulations and a focus on sustainability, is driving the replacement of traditional roofing systems with advanced membrane solutions. Flashing and weathering membranes are essential components in these retrofits, providing durable sealing at roof edges, penetrations, and transitions. The segment is also benefiting from the growing adoption of cool roofs and green roofs, which require specialized flashing details. Through 2035, the segment is expected to grow at a moderate pace, supported by government incentives for energy-efficient building upgrades and the increasing frequency of extreme weather events that necessitate robust waterproofing. Demand-side indicators include commercial construction spending, roof replacement cycles, and the implementation of building energy codes. The trend toward performance-based specifications and longer warranty periods is pushing demand toward premium membrane products. Major roofing contractors and building owners are increasingly prioritizing lifecycle cost optimization, favoring membranes with proven durability and low maintenance requirements. Current trend: Moderate growth supported by building energy codes.
Major trends: Adoption of cool roofs and green roofs requiring specialized flashing, Stricter building energy codes driving retrofit demand, Shift toward performance-based specifications and extended warranties, and Increasing use of BIM for retrofit planning and material selection.
Representative participants: GAF Materials Corporation, Firestone Building Products, Carlisle Companies Inc, Soprema Group, and IKO Industries Ltd.
Specialty end-use applications encompass a diverse range of uses, including infrastructure projects, marine environments, and extreme climate conditions. These applications require membranes with specialized properties, such as high UV resistance, chemical resistance, or the ability to perform in extreme temperatures. The segment includes flashing and weathering membranes used in bridges, tunnels, and other critical infrastructure, where long-term durability is paramount. It also covers applications in cold climates, where membranes must remain flexible at low temperatures, and in hot, arid regions, where UV degradation is a concern. Through 2035, the segment is expected to grow at a moderate pace, driven by infrastructure investment programs and the need for climate-resilient construction. Demand-side indicators include public infrastructure spending, the frequency of extreme weather events, and the adoption of performance-based building codes. The trend toward high-purity and specialty formulations is particularly pronounced in this segment, as end-users require membranes that meet stringent performance criteria. Major companies are investing in R&D to develop membranes tailored to specific environmental challenges, creating opportunities for differentiation and premium pricing. Current trend: Niche but growing with infrastructure and extreme environment needs.
Major trends: Development of membranes for extreme temperature and UV exposure, Growing infrastructure investment in emerging markets, Increased focus on climate resilience in building design, and Rising demand for high-purity and specialty formulations.
Representative participants: DuPont de Nemours, Inc, Sika AG, BASF SE, GCP Applied Technologies, and Henry Company.
The formulation and compounding segment represents a smaller but important part of the flashing and weathering membrane market, involving the production of customized membrane blends for specific applications. This segment includes manufacturers that compound polymers, additives, and fillers to create membranes with tailored properties, such as enhanced adhesion, flexibility, or fire resistance. Demand in this segment is driven by the need for product differentiation and the growing complexity of building envelope requirements. Through 2035, the segment is expected to remain stable, with growth tied to the overall market expansion and the increasing demand for specialty formulations. Demand-side indicators include the number of membrane product launches, the adoption of advanced polymer technologies, and the level of R&D investment by major manufacturers. The trend toward vertical integration among large membrane producers is influencing this segment, as some companies are bringing compounding in-house to reduce costs and improve quality control. However, independent compounders continue to play a role, particularly in niche applications where specialized expertise is required. Major companies in this segment focus on developing proprietary formulations that offer performance advantages over standard products. Current trend: Stable with customization demand.
Major trends: Development of proprietary polymer blends for enhanced performance, Vertical integration of compounding by large membrane producers, Growing demand for fire-resistant and low-VOC formulations, and Use of recycled and bio-based polymers in membrane production.
Representative participants: BASF SE, Dow Inc, Sika AG, Carlisle Companies Inc, and Polyglass S.p.A.
Interactive table based on the Store Companies dataset for this report.
Asia-Pacific dominates the flashing and weathering membrane market, driven by rapid solar PV deployment in China, India, and Southeast Asia. The region’s construction boom, coupled with government renewable energy targets, fuels demand. China alone accounts for a significant share of global solar installations, boosting membrane consumption. Local manufacturers are expanding capacity, while international players seek partnerships to access this high-growth market. Direction: Fastest-growing region.
North America is a mature but growing market, supported by commercial roofing retrofits and the Inflation Reduction Act’s incentives for solar and energy-efficient buildings. The region’s stringent building codes and FM Approvals requirements favor premium membrane products. The United States leads demand, with Canada contributing to growth in cold-climate applications. Supply chain localization and sustainability trends are shaping the competitive landscape. Direction: Steady growth.
Europe’s market is driven by the EU’s Green Deal, energy efficiency directives, and a strong focus on sustainable construction. The region’s aging building stock presents significant retrofit opportunities. Germany, France, and the UK are key markets. Strict CE marking and REACH compliance create barriers to entry, favoring established players. The shift toward bio-based and recyclable membranes is gaining traction, aligning with circular economy goals. Direction: Moderate growth.
Latin America is an emerging market with growing solar installations, particularly in Brazil, Chile, and Mexico. Infrastructure development and urbanization support demand for flashing and weathering membranes. However, economic volatility and regulatory uncertainty can hinder growth. Local production is limited, making the region reliant on imports. International companies are increasingly targeting this market as solar capacity expands. Direction: Emerging growth.
The Middle East & Africa region shows potential, driven by large-scale infrastructure projects and solar initiatives in the Gulf states. Harsh climatic conditions necessitate high-performance membranes, creating opportunities for premium products. However, the market remains small due to lower construction activity in parts of Africa. South Africa and the UAE are key markets. Import dependence and logistical challenges are notable constraints. Direction: Slow but steady growth.
In the baseline scenario, IndexBox estimates a 7.5% compound annual growth rate for the global flashing and weathering membrane market over 2026-2035, bringing the market index to roughly 185 by 2035 (2025=100).
Note: indexed curves are used to compare medium-term scenario trajectories when full absolute volumes are not publicly disclosed.
For full methodological details and benchmark tables, see the latest IndexBox Flashing and Weathering Membrane market report.
This report provides an in-depth analysis of the Flashing and Weathering Membrane market in the world, covering market size, growth trajectory, demand structure, supply capability, trade flows, pricing, competitive landscape, and forecast to 2035.
The study is designed for manufacturers, distributors, importers, exporters, investors, procurement teams, advisors, and strategy teams that need a consistent, data-driven view of market dynamics and a transparent analytical definition of the product scope.
This report covers the global market for flashing and weathering membranes, which are flexible or semi-rigid sheet materials used to seal joints, transitions, and penetrations in building envelopes against moisture ingress and environmental exposure. The scope includes membranes designed for roof flashing, wall flashing, window and door flashing, and below-grade waterproofing applications, encompassing both self-adhered and mechanically fastened variants.
The report combines the standard market-statistics backbone with strategic chapters that are useful for commercial planning, sourcing decisions, market entry, competitor monitoring, and portfolio prioritization.
The market is segmented into decision-relevant buckets so that demand drivers, pricing logic, supply constraints, and competitive positions can be compared across the same analytical frame.
The classification coverage encompasses products categorized under building construction waterproofing materials, specifically those used for flashing and weathering applications. The report segments the market by product type (flashing and weathering membrane, functional grades, high-purity grades, specialty formulations), by application (solar mounting, industrial processing, formulation and compounding, specialty end-use applications), and by value chain stage (feedstock and input sourcing, processing and formulation, quality control and certification, distributors and end-use manufacturers).
Coverage includes global totals, major demand markets, production and sourcing hubs, leading exporters and importers, and country profiles for the top national markets.
The report combines official statistics, trade records, company disclosures, product-level evidence, and analyst validation. Data are standardized, reconciled, and cross-checked to keep market sizing, trade flows, pricing, and forecasts comparable across countries and time periods.
All indicators are mapped to a consistent product definition and reviewed against the segmentation framework used in the Table of Contents.
Report Scope and Analytical Framing
Concise View of Market Direction
Market Size, Growth and Scenario Framing
Commercial and Technical Scope
How the Market Splits Into Decision-Relevant Buckets
Where Demand Comes From and How It Behaves
Supply Footprint, Trade and Value Capture
Trade Flows and External Dependence
Price Formation and Revenue Logic
Who Wins and Why
Where Growth and Supply Concentrate
Commercial Entry and Scaling Priorities
Where the Best Expansion Logic Sits
Leading Players and Strategic Archetypes
Detailed View of the Most Important National Markets
How the Report Was Built
Leading in liquid-applied and sheet membranes
Major TPO and EPDM producer
Subsidiary of Standard Industries
Part of Holcim Building Envelope
Key chemical supplier for membrane formulations
Innovator in weather-resistant sealants
Strong in European and North American markets
Integrated building envelope solutions
Major in commercial and residential
Acquired by Carlisle in 2021
Tyvek brand for building envelope
Parent of Tremco, Carboline, and others
Specialist in commercial roofing systems
Family-owned, major in residential
Part of Saint-Gobain group
Broad portfolio including Weber and CertainTeed
Now part of Standard Industries
Owner of Icopal, Monier, and Braas
Subsidiary of Mapei Group
Construction chemicals specialist
Strong in Middle East and Asia
Dr. Fixit brand leader in India
Key player in Southeast Asia
Innovator in flashing for solar roofs
Specialist in seamless flashing systems
Premium commercial roofing brand
Known for high-performance weathering
Supplier of raw materials for membranes
Produces reinforced flashing films
Now integrated into Standard Industries
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San Antonio Report
Nonprofit journalism for an informed community
A new program could help San Antonio residents benefit from solar power, even if they have no roof for solar panels.
CPS Energy is expanding a community solar power program that lets San Antonio residents buy solar panels that are installed in other, prime locations in the area. In exchange, customers get a credit on their electricity bill by selling the solar energy back to CPS Energy.
The utility is collaborating with Big Sun Solar, a San Antonio-based solar company that works on commercial solar projects across Texas. Robert Miggins, CEO and co-founder of the company, said the program targets residential customers, but is open to anyone with a CPS account.
“Let’s say you rent a house. Let’s say you don’t want to cut down trees,” Miggins said. “Let’s say your roof faces the wrong direction … let’s say you don’t like how solar panels look or you don’t know how long you’ll live somewhere.”
Anyone who can’t put a solar panel on their own roof is a good fit, Miggins said.
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Customers can choose to purchase solar panels in a shared, community facility and could potentially buy enough panels to offset 100% of their electric consumption, according to a CPS Energy press release.
CPS Energy collaborated with Big Sun Solar on a smaller pilot program in 2019 and announced plans for a larger community solar project in 2023. It’s part of the utility’s push to both diversify its power supply and make its electricity generation more sustainable in the face of climate change.
A single solar panel costs $1,240 and could take $115 over the course of a year off their power bills, according to Miggins. The program lasts for 20 years and savings from one solar panel could add up to $2,300.
“It’s a commercial-grade module, which is always bigger than a residential module,” Miggins said. “It’s got more solar cells and is taller and wider.”
Each panel can generate 620 watts per hour. Miggins emphasized that customers own the panel outright. They can sell them to a waitlist of other interested customers or move the panels to another location entirely, if they choose.
Miggins added that Big Sun Solar installs the panels, pays for insurance and maintains them. The company funds that through customers’ initial purchase and takes a small fraction of the revenue from the sale of solar power to CPS Energy.
He could not disclose the size of that fraction. Miggins said owners of the panels through the program would sell electricity to CPS Energy at 10 cents per kilowatt hour.
CPS Energy typically sells power at 12 to 13 cents per kilowatt hour, he said. Miggins acknowledged that customers that built solar panels on their own roof could sell the electricity back to CPS Energy at the 12 to 13 cent rate.
A pilot program in 2019 which made five megawatts of solar power available sold out, Miggins said. The new program will have 50 megawatts available.
That’s enough power for 10,000 homes, according to CPS Energy.
Miggins said the program will be rolled out in two phases. First, 20,000 megawatts will be sold and built, or around 39,000 solar panels. If that first phase is successful, the program will scale up to the full 50,000 megawatts — roughly 100,000 solar panels.
Solar panels will be installed first at the San Antonio Food Bank, which is leasing roof space to Big Sun Solar. Then, the company will start building solar facilities on rented land in Bexar County that has good exposure to sunlight.
Miggins said CPS Energy customers can sign up for the program on the company’s website and make a $100 refundable deposit or seek to purchase the panels immediately.
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Jasper Kenzo Sundeen covers business for the San Antonio Report. Previously, he covered local governments, labor and economics for the Yakima Herald-Republic in Central Washington. He was born and raised… More by Jasper Kenzo Sundeen
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⚡ Quick Read
The global solar manufacturing landscape has been increasingly defined by the transition from PERC to TOPCon (Tunnel Oxide Passivated Contact) solar cell technology. As manufacturers race to achieve higher conversion efficiencies, intellectual property (IP) disputes have become common. The litigation between Canadian Solar and Maxeon Solar Technologies centered on three specific patents related to TOPCon architecture, which is currently the most sought-after technology for utility-scale solar projects in India.
Canadian Solar confirmed that the legal proceedings initiated by Maxeon in the United States have been fully resolved. While specific financial terms of the settlement remain confidential, the resolution effectively removes a significant legal cloud that had been hanging over the deployment of Canadian Solar’s high-efficiency n-type modules. The dispute involved complex claims regarding the manufacturing processes and structural design of TOPCon cells, which are critical for maximizing power output in limited-space installations.
For Indian EPC contractors and solar developers, this settlement provides much-needed stability. With the Indian market aggressively adopting TOPCon modules to meet higher efficiency requirements and lower Levelized Cost of Energy (LCOE) targets, supply chain certainty is paramount. Legal disputes involving major Tier-1 module suppliers often lead to delivery delays or uncertainty regarding the long-term availability of specific product lines. By resolving this litigation, Canadian Solar ensures that its TOPCon product roadmap remains accessible to the Indian market without the risk of injunctions or supply disruptions. Developers can now proceed with procurement strategies involving these modules with greater confidence in the manufacturer’s IP standing.
The industry is expected to see a consolidation of technology standards as manufacturers move past initial patent hurdles. As India continues to scale its domestic manufacturing capacity under the Production Linked Incentive (PLI) scheme, local manufacturers may also look toward licensing agreements to avoid similar IP conflicts. The resolution of this case serves as a bellwether for the broader renewable energy sector in India, where the rapid adoption of advanced cell technologies is essential to meeting the country’s ambitious 500 GW non-fossil fuel capacity target by 2030. Maintaining a clear legal landscape for technology transfer remains a critical component of sustaining the rapid growth of the Indian renewable energy sector.
Aditya Pathre is the Founder of MVApulse and covers India’s renewable energy sector, including solar, wind, battery energy storage systems (BESS), green hydrogen, transmission infrastructure, renewable energy policy and competitive bidding. His reporting focuses on project developments, market trends, government policies and energy transition across India.
India’s Power Sector Intelligence Portal
MVApulse is an independent publication covering India’s renewable energy sector including solar, wind, BESS, transmission, green hydrogen, EPC and power markets.
Copyright © 2026 MVApulse. Powered by Swadi Innovative Technologies Pvt Ltd.

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⚡ Quick Read
The regulatory landscape in Uttarakhand has seen a significant development as the Uttarakhand Electricity Regulatory Commission (UERC) recently issued an order dismissing a petition that sought a review of the trading margins prescribed for solar and standalone battery storage projects. Trading margins represent a vital component of the financial viability for intermediaries in the power sector, and any adjustment to these figures directly impacts the profitability of energy procurement strategies.
In its latest ruling, the UERC examined the arguments presented by the petitioner regarding the necessity of revising the existing trading margins. After a thorough review, the Commission concluded that there was no “error apparent on the face of the record” in its earlier order. By maintaining the status quo, the regulator has effectively signaled its commitment to the existing framework for solar and battery energy storage system (BESS) transactions within the state. The decision reinforces the current regulatory stance, ensuring that the previously established margins remain in force for market participants.
For EPC contractors and solar developers operating in the region, the UERC’s decision provides much-needed regulatory certainty. When bidding for projects or entering into power purchase agreements, developers rely on stable margin structures to calculate their internal rate of return (IRR). Frequent changes to these margins can lead to financial volatility and hinder project bankability. By rejecting the review, the commission has provided a clear signal that the current tariff and margin guidelines are settled, allowing developers to proceed with their project pipelines without the looming threat of immediate regulatory shifts in trading costs.
Stakeholders will now likely focus on the implementation of the existing orders, ensuring that all procurement activities align with the commission’s directive. While the petition has been dismissed, the broader India renewable energy sector continues to monitor how state regulators balance the interests of power traders, developers, and distribution companies. As India accelerates its transition toward a greener grid, the role of consistent policy frameworks in states like Uttarakhand remains essential for attracting long-term investment in solar and BESS infrastructure.
Aditya Pathre is the Founder of MVApulse and covers India’s renewable energy sector, including solar, wind, battery energy storage systems (BESS), green hydrogen, transmission infrastructure, renewable energy policy and competitive bidding. His reporting focuses on project developments, market trends, government policies and energy transition across India.
India’s Power Sector Intelligence Portal
MVApulse is an independent publication covering India’s renewable energy sector including solar, wind, BESS, transmission, green hydrogen, EPC and power markets.
Copyright © 2026 MVApulse. Powered by Swadi Innovative Technologies Pvt Ltd.

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A proposed $67 billion merger between Florida-based NextEra Energy and Dominion Energy is drawing scrutiny from Virginia clean energy trade groups and state officials concerned over the future of distributed solar policy and net metering protections in the Commonwealth.
According to reporting by the Virginia Center for Investigative Journalism (VCIJ) at WHRO, distributed generation advocates warn that NextEra’s regulatory track record in Florida could signal headwinds for Virginia’s rooftop solar market.
The transaction, initially proposed in May 2026 and formally submitted to the Virginia State Corporation Commission (SCC) on July 15, would merge Dominion’s vast regulated utility footprint with NextEra’s massive generation portfolio, creating the largest regulated electric power company in the United States.
The deal comes as Dominion seeks capital to build out generation infrastructure to meet rapidly growing data center demand in Northern Virginia. However, local solar installers expressed concern to VCIJ at WHRO over how the acquisition might impact the state’s distributed energy sector.
Net metering and regulatory precedents
Central to the industry’s concern is NextEra’s regulated utility subsidiary, Florida Power & Light (FPL), which has historically backed measures aimed at reforming or reducing net energy metering (NEM) credit rates. 
In 2022, FPL supported Florida legislation designed to restructure net metering credits and implement higher grid interconnection fees. The measure was ultimately vetoed by Florida Gov. Ron DeSantis.
In Virginia, distributed solar development is largely governed by the 2020 Virginia Clean Economy Act (VCEA), which established full retail-rate net metering and expanded third-party power purchase agreements (PPAs). 
“Everyone in my network is aware that Florida Power & Light is considered the most hostile with residential solar,” Robin Dutta, executive director of the Chesapeake Solar and Storage Association (CHESSA), told VCIJ at WHRO. “That’s their reputation.”
Dutta said local, non-utility solar contractors operating exclusively in Virginia face heightened market risk if utility policies shift toward restricting rooftop solar monetization.
In addition to net metering debates, consumer advocates like Solar United Neighbors (SUN) pointed to secondary regulatory barriers in Florida. 
Speaking with VCIJ at WHRO, representatives highlighted FPL’s requirement for commercial liability insurance on residential systems between 10 kW and 100 kW as a potential policy friction point should NextEra’s operational philosophies spread to Virginia.
Utility positioning and state intervention
Dominion Energy said the transaction will not disrupt Virginia’s clean energy mandates or clean energy statutes. In testimony filed with the SCC in July, Ed Baine, president of Dominion Energy Virginia, affirmed the company’s regulatory commitments.
“The Company will remain fully dedicated to the nation-leading public policy priorities that Virginia has established, including through the Virginia Clean Economy Act,” Baine stated in the merger petition.
Neither NextEra Energy nor FPL responded to requests for comment from VCIJ at WHRO regarding their stance on Virginia’s distributed solar market.
The regulatory review process has drawn state-level political involvement. Virginia Gov. Abigail Spanberger filed a formal intervention with the SCC on August 17.
The SCC’s initial 60-day review period can be extended by an additional 120 days. Beyond Virginia regulators, the proposed acquisition requires approval from shareholders, utility commissions in North and South Carolina, the Federal Energy Regulatory Commission (FERC), and the Nuclear Regulatory Commission (NRC). The companies previously indicated the transaction is expected to close in late 2027.
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The new issue of pv magazine Global is out now!
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Solar panels can cut household energy bills and make a home more appealing to buyers
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Solar panels can reduce reliance on the grid and cut electricity bills, but there is another potential benefit to consider: they could make your home more attractive when it comes to selling it.
Buyer interest in energy-efficient homes appears to be growing. Rightmove says mentions of solar panels in property listings increased by almost 40 per cent in 2025 compared with the previous year, suggesting sellers and estate agents increasingly see them as a feature worth highlighting. With electricity prices also remaining high, the prospect of buying a home that already generates some of its own power can be appealing.
That does not mean installing solar panels will automatically add thousands of pounds to your asking price. Estimates of the potential uplift vary considerably, and factors including the age and condition of the system, whether you own the panels outright, your property’s location and its overall energy efficiency can all influence what buyers are prepared to pay.
Keep reading to find out whether solar panels add value to a house, how they can affect its saleability and what homeowners should consider before installing a system primarily as an investment.
A good way of tackling this question is thinking about home improvements in general. Ones that are critical, like fixing a leaky roof, are likely to generate good returns since the home will be very unattractive without the work being done.
Similarly, a loft conversion or extension which makes the usable size of the home bigger will increase a home’s value in a fairly reliable way.
But optional improvements like solar panels are harder to quantify. This is for a number of reasons.
Firstly, the idea of owning a home with solar panels is still a fairly new one. It won’t be like weighing up the value of an extra bathroom or a new kitchen for most buyers. Without research, most people won’t know the value of a solar setup.
Secondly, as you can see from our guide here, owning solar panels and managing them well does take a little effort. You need to set them up correctly to get paid for the electricity you don’t use, and you may need to switch tariffs each year. That does take some time and effort.
And although most homeowners spend very little time looking at their own roofs – or even roofs in general – they can divide opinion on aesthetics.
Read more: Compare free solar panel quotes
Thirdly, and perhaps most importantly, making a firm estimate on any improvement is difficult, and those trying to do so are often trying to sell those improvements and don’t come from a place of neutrality.
You can’t sell the same property twice at the same time, once with panels and once without to show how much value they add. Other, bigger factors such as the state of the housing market or rising or falling interest rates will make a far bigger impact on house prices than a £6,500 to £8,000 solar installation.
However, there are signs that solar panels are becoming a more recognised selling point. Rightmove’s 2025 Greener Homes Report found that mentions of solar panels in property listings increased by 37 per cent year on year. Its consumer research also found that 30 per cent of people believe green upgrades add value to a home, while 19 per cent think they make properties more attractive to buyers.
That doesn’t prove solar panels themselves increase a home’s sale price by a particular amount, but it suggests energy-saving technology is becoming more visible in the property market.
In short, these estimates have very little to back them. Most people will see cheaper electricity bills as a plus, but they may struggle to put a price on that, especially when buying a home is partly about taste and emotion, rather than pure numbers.
Those expecting that an investment of one sum will boost the price of their house by more than that sum will probably be disappointed. That’s because buyers who want a solar array can just get their own.
Fitting them does not cause the mess or inconvenience of a new kitchen or bathroom, and they don’t improve the look or feel of the home either. So you aren’t doing the next owner such a massive favour.
It’s important to remember that solar panels are not equally effective across the UK, and this can affect your ROI on the investment. Factors like roof angle and sun exposure vary by region and, crucially, so does house price growth.
Southern England sees significantly higher solar yields than northern Scotland, thanks to better sun exposure.
Meanwhile, homes in higher-value regions may see more uplift in absolute terms, but percentage-wise, returns are still modest.
Local planning regulations or conservation area restrictions may also limit what kind of installation is allowed.
While there’s no guaranteed uplift in property value when getting solar panels, the following factors can make a difference:
Installing solar panels may increase your home’s appeal and potentially its value, but you shouldn’t assume that every pound spent on a system will be reflected in the eventual sale price.
Even if there was a good estimate for the improvement in the value of your house that solar panels could make, you ought to think twice before using it for the same reason that movements in the UK’s average house price might not apply to you. That is because your house’s price might not behave like the average house’s price.
You could easily spend £8,000 and see your house price drop, not because of your investment but because demand in your area has fallen or the cost of borrowing has risen.
Here’s the most useful advice: don’t buy solar panels for your home if all you want to do is improve its sale price. Do buy them if you want to cut your energy bills.
In most cases, solar panels make a home easier to sell, not harder, provided the system is owned outright and still under warranty. Buyers are increasingly interested in properties with lower running costs, and the promise of free or cheaper electricity for years to come is a strong selling point.
However, selling can be more complicated if the panels are leased or installed under a rent-a-roof scheme, where a third party owns the system. In those cases, buyers may need to take over the agreement, which can slow the sale or deter mortgage lenders. To avoid this, homeowners considering a future sale often choose to buy panels outright or settle any lease before putting their property on the market.
Good documentation – including the installation certificate, warranty details, and energy generation data – can also help reassure buyers that the system is well maintained and adds genuine value.
Read more: Are Octopus solar panels worth it? Expert review
The cost of solar panels depends on the size of the array. The table below will give you some indication, with array costs taken from a survey of installers conducted by The Independent and energy prices from the Energy Saving Trust.
Home type
Typical system
Current installed cost
Two-bed / small home
3kW
£5,000-£6,500
Three-bed / typical family home
4-5kW
£6,500-£8,000
Four-bed / higher use
5-6kW
£7,500-£9,500
As a rough guide, The Independent’s latest analysis suggests a typical 4-5kW system costs around £6,500 to £8,000 in 2026. Actual costs vary according to the number and type of panels, roof layout, installer and whether battery storage is included. For more, see our guide to the true cost of solar panels.
A typical solar installation can take around eight to 12 years to pay for itself through lower electricity bills and export payments, although the exact period depends on the upfront cost, how much solar electricity you use yourself, your export tariff and your roof’s generation potential.
To do the maths we are using an address in London, assuming a family of three and typical use – no heat pumps, high daytime usage or electric car charging.
Other assumptions include no shade on the panels and that someone is in, using power for about half the day and an export price of 15p per kilowatt hour (p/kWh). Other than a new inverter, no other maintenance costs are assumed, and no financing costs are assumed. The roof is roughly south-east facing.
Much will depend on what price you get for your exported electricity. Tariffs vary widely. Smart Export Guarantee rates vary significantly between suppliers, and some of the better-paying tariffs have eligibility conditions. It is therefore worth comparing export tariffs when calculating your potential return, rather than assuming a fixed rate for the lifetime of the system.
Energy prices have a significant effect on solar-panel payback because every unit of solar electricity you use at home is one you do not have to buy from your supplier.
From 1 July to 30 September 2026, the average electricity unit rate under Ofgem’s price cap is 26.11p/kWh for customers paying by Direct Debit. Higher grid electricity prices can therefore increase the savings available from generating and using your own power.
The Energy Saving Trust has a handy calculator you can use to ascertain your savings from having solar panels and the ROI on your investment.
Join thought-provoking conversations, follow other Independent readers and see their replies
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Tesla Reportedly Kills Solar Roof Tiles Amid Financial Viability Concerns—Shifts Focus to Conventional Pa  Benzinga
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Perry County residents will have a chance to learn about the Panther Energy Project next month. Arevon Energy is building a solar energy project with an expected completion date in late 2027 or early 2028.
They’re holding an open house on September 2nd from 5 to 7 p.m. at 15 North Main Street in Pinckneyville.
On their project website, Arevon says this project will generate enough power for 37,000 homes. They say the facility will provide economic development and tax revenues while pledging to work with local citizens and county officials.
Arevon is building the Big Muddy Solar Project. In that project solar panels are being installed on 600 acres in Jackson County five miles north of Murphysboro on State Route 127. They are scheduled to be done by the end of 2026

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Sunshine and clouds mixed. High 83F. Winds NNE at 5 to 10 mph..
Cloudy skies early, then off and on rain showers overnight. Low 67F. Winds light and variable. Chance of rain 70%.
Updated: August 21, 2026 @ 9:22 am

XI’AN, China, Aug. 21, 2026 (GLOBE NEWSWIRE) — The 2026 Elektrek American Solar Challenge (ASC) has recently concluded. Following an 8-day grueling cross-continental race across the United States, Belgium’s Innoptus Solar Team and the Netherlands’ Delft Solar Team – both equipped with LONGi’s Back Contact (BC) technology – stood out amid global competitors and secured the championship and runner-up spots, respectively.
As one of the world’s most prestigious and influential competitions for solar-powered vehicles, the ASC features an ultra-long race route, complex road conditions and volatile weather. It serves as an ultimate comprehensive test of a solar car’s energy system, aerodynamic design and team race strategy.
The Innoptus Solar Team covered a total distance of 4,298.9 kilometers to take home the championship, marking the first time a European team has ever won the ASC title. No European squad had claimed the top prize since the competition’s inception, making this achievement a historic milestone. The Delft Solar Team finished second with a total driving distance of 4,080.5 kilometers.
Both teams relied on LONGi BC technology products as their vehicles’ core power supply. Under rigorous real-race conditions, the modules delivered steady power output and outstanding conversion efficiency. Their versatile, high-performance design enabled consistent energy supply throughout the entire endurance race.
LONGi’s engagement in solar vehicle racing has grown from single-event sprint races to long-distance endurance contests, and from supporting one team to backing two top European squads simultaneously. Its BC technology has become the trusted choice for elite teams tackling extreme racing conditions.
LONGi’s cooperation with solar racing teams centers on joint technological innovation rather than financial sponsorship.
Only 6 square meters of solar cells can be exposed on a race car’s roof, and the entire photovoltaic system must deliver ultra-high conversion efficiency while remaining lightweight, flexibly adaptable and reliably durable over thousands of kilometers – performance benchmarks far exceeding standard civilian PV applications. The customized flexible modules adopted by the Belgian team and high-efficiency cell solution used by the Dutch team represent differentiated offerings from LONGi BC technology, tailored to distinct technical architectures and vehicle designs.
The unanimous selection of LONGi by these two world-class teams stands as rigorous real-world validation of LONGi BC technology’s strengths in conversion efficiency, product stability and multi-scenario adaptability.


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India is counting on increasing investments in battery storage to help abate the mounting curtailments of solar power that the grid is currently unable to absorb.
Projects that are not equipped with battery storage are unlikely to find buyers, with almost 42 gigawatts of planned capacity yet to sign offtake contracts, Renewables Secretary Santosh Kumar Sarangi said on Friday.
Among the most at risk are about 18 gigawatts of solar-only projects and another 14 to 15 gigawatts of capacity awarded at high prices, he said at the BNEF Summit in New Delhi.
In India, renewables additions have been led by photovoltaic, causing a day-time supply glut, particularly during summers when radiation is stronger. About 11% of solar power generated in India during the hottest months this year was lost to grid curtailments, even as demand hit a record.
Grids around the globe are struggling to keep pace with the rapid expansion of solar and wind fleets, creating periods of excess electricity that force operators to shut down a portion of generation capacity to protect equipment and prevent blackouts.
India’s transmission system failed to absorb more than 8 billion kilowatt-hours of power in April to June, when 63 billion actually reached the system. Peak curtailment was seen in May, when scorching heat sent electricity use to all-time high.
Solar developers are now adding battery storage to attract buyers that need supplies throughout the day, Sarangi said.
Almost 21 gigawatts of the country’s renewable energy projects have only part-time access to the grid, putting them at a greater risk of curtailments, which is hampering expansion and threatening to slow energy transition.
States in the northern and western regions have struggled to build grid networks that match the expansion in solar energy.
Parikh Worldwide Media is the largest Indian-American publishing group in the United States. The group publishes five periodicals – “News India Times,” a national weekly newspaper; “Desi Talk in New York,” a weekly newspaper serving the New York-New Jersey-Connecticut region; and “Desi Talk in Chicago,” a weekly newspaper serving the Greater Chicago area and the Midwestern states; and “The Indian American,” a national online quarterly feature magazine, and the Gujarat Times, a Gujarati language weekly. The combined circulation and readership of these publications make the media group the most influential in the ethnic Indian market.

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Law, Technology & Innovation

Hannah Gaskill//August 20, 2026//
Former coalfield in Western MD getting solar energy
State policies encourage the development of projects such as the Annapolis Solar Park. (Photo courtesy of the City of Annapolis)

Hannah Gaskill//August 20, 2026//

The Maryland Board of Public Works approved an agreement Wednesday to utilize solar energy in a Western Maryland former coal district, representing a fundamental difference in state and federal energy priorities.
“What is indisputable in all this is that clean-energy projects that are ready to go right now are the ones that are also the ones most directly under attack by this federal administration, who is using energy policy like an ideology, who is not allowing data — nor science — to be able to lead the conversation but just simply internet conspiracy theories and talking points,” Gov. Wes Moore, a Democrat, said at an Annapolis meeting Wednesday. 

The Board of Public Works approved a long-term, $470 million solar power purchase agreement with REV Renewables, a clean-energy generation and storage company, slated to provide 250,000 megawatt-hours of renewable energy via the Jade Meadow III Solar Project located on the reclaimed Lower Georges Creek Coalfield in Garrett County.
Moore said the coalfield had been “periodically” used for mining operations since the 1800s but shuttered in the early 2000s, “mainly because of the costs.”
The Jade Meadow III Solar Project is currently active on the PJM Interconnection queue and anticipated to be functional for state energy accounts by 2028. Maryland is one of 13 states connected to PJM’s power grid, which also covers Washington, D.C.

The 20-year power purchase agreement is slated to save the state $300 million and provide enough renewable electricity to power nearly 15% of Maryland’s portfolio starting in 2028, officials said.
During Wednesday’s meeting, Moore said the agreement will aid in strengthening the grid and lower Maryland’s skyrocketing utility costs.
“This agenda item will make sure that we are utilizing all the various assets that are necessary … to provide relief while also making sure that we can have a grid that is fortified and a grid that is sustainable because in order to strengthen the grid while also lowering costs, we have to focus on renewable energy, and that is not because it’s an ideology,” he said.
“It’s because renewable energy is the cleanest, and it’s also the cheapest and the fastest way for us to be able to sustain energy here inside the state of Maryland.”

The approval of the purchase agreement comes two months after President Donald Trump announced that millions in federal funds will be funneled toward restarting the AES Warrior Run coal plant in Allegany County. Warrior Run is a 229-megawatt facility in Cumberland that shuttered in June 2024. 
The president’s actions were made possible through the invocation of the Defense Production ⁠Act — a Cold War-era defense power that gives presidents authority over national security-related industries.
“Our action will allow these facilities to invest in upgrades, will extend their operational lives for decades into the future, reinforce the reliability of our electric grid … and, most importantly, keep our electricity prices very low for the American people,” Trump said at the time of the announcement. 
Maryland Republicans celebrated Trump’s actions as a step toward increasing Maryland’s energy supply. But the president’s preference for coal and other fossil fuels conflicts with Maryland Democrats’ commitment to shift to green energy generation.
In 2024, Moore issued an executive order setting a goal of 100% clean energy in Maryland by 2035. The policy dovetails with the state’s Climate Pollution Reduction Plan, which will require that 100% of energy consumed in Maryland be generated by clean and renewable sources by 2035.
According to the state Department of the Environment’s website, the Climate Pollution Reduction Plan is poised to provide up to $1.2 billion in public health benefits, $2.5 billion in increased personal income and a net 27,400 jobs by 2031.
“The Administration’s stated goals are unattainable without purchasing renewable energy,” reads the Board of Public Works’ meeting agenda item brought by the Maryland Department of General Services reads.

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Insolation Energy is transitioning from a pure-play solar module assembler to an integrated clean tech platform. Key milestones include 5.5 GW of operational module capacity, a 4.5 GW solar cell factory under construction in Madhya Pradesh, and long-term plans for a 4.5 GW wafer and ingot ecosystem to eliminate China import dependence.
Market snapshot: Insolation Energy is aggressively executing a backward integration strategy to expand its solar manufacturing footprint. While the input alert claims a 5.5 GW cell capacity (as stated in the source alert; not independently verified), official company disclosures clarify that 5.5 GW represents its current operational module capacity. Under its expansion roadmap, the company plans to establish a 4.5 GW solar cell facility and a 4.5 GW captive wafer and ingot plant to build a fully integrated domestic solar platform.
Insolation Energy's financial trajectory reflects the classic J-curve of a scaling hardware manufacturer. Operating 5.5 GW of module capacity while importing high-cost cells exposes the company to global commodity volatility. The real profitability inflection point depends on the Narmadapuram cell plant's commissioning in late FY27, which is expected to support EBITDA margins by localizing core production steps.
With the Indian government strengthening the Approved List of Models and Manufacturers guidelines, integrated local players will enjoy structural preferences. Insolation Energy's vertical integration positions it well to win major public tenders, but the high capex requirement for cell and wafer lines remains a heavy balance sheet burden.
Market Bias: Neutral
While top-line growth is highly impressive with Q1 FY27 revenue rising 104.68% YoY, bottom-line contraction of 11.81% and high capex requirements highlight near-term execution and margin risks.
Overweight: Solar Power Manufacturing, Renewable Energy Utility Suppliers
Underweight: Import-Dependent Solar Assembly
Trigger Factors:
Time Horizon: Medium-term (3-12 months)
The Indian solar manufacturing space is scaling rapidly under policy incentives, yet a major imbalance exists as India holds massive module assembly capacity but relies heavily on imported solar cells and wafers. Vertical integration is becoming a business necessity rather than a choice to remain competitive.
In July 2026, Insolation Energy's subsidiary secured a ₹558.29 crore solar PV module supply order from NTPC Renewable Energy. Additionally, the company reported its Q1 FY27 results on August 13, 2026, showing revenue growth of 104.68% YoY to ₹740.7 crore alongside a net profit of ₹38.02 crore.
Insolation Energy is making a vital transition toward full vertical integration. If successful, localizing solar cell and wafer production will unlock substantial margin power and shield the company from global supply constraints.
High Performance Trading with SAHI.
Disclaimer: This news section may include AI-generated or AI-assisted news, summaries, drafts, or insights. All content is subject to human review before publication. While we aim for accuracy, readers should independently verify information before relying on it.
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By: Luis Reyes
Published: Aug 20, at 7:30am ET
Agrivoltaics has settled into a fairly boring formula. Lift the panels high enough to drive a tractor under them, plant something that tolerates shade, then collect money twice off the same acre. Germany has been doing this long enough to have written a technical standard for it.
What SUNfarming wants to test in North Rhine-Westphalia breaks the formula in one specific way. There is no soil.
The company said on August 15 that it is developing and testing hydroponic growing systems under Agri-PV arrays, working with TH Köln and NourTec GmbH. Lettuce roots sitting in nutrient water, under glass-glass modules, on land that German law still has to classify as a farm.
That last part is where this gets interesting, and nobody in the announcement wanted to talk about it.
SUNfarming’s post reads like news. It is closer to a progress update.
TH Köln’s official project page lists CircularFarming.IN.NRW as running from March 2025 to February 2028, with SUNfarming and NourTec as the two industrial partners. The work is split across two faculties and two institutes, led by Prof. Mohieddine Jelali at the Cologne Lab for Artificial Intelligence and Smart Automation and Prof. Miriam Sartor at the Circular Transformation Lab in Gummersbach.
The project sits under NRW’s GreenEconomy.IN.NRW competition and draws on the state’s ERDF and Just Transition Fund programme, which carries roughly 1.9 billion euros of EU money inside a total investment volume of about 4.2 billion once state co-financing and project owner contributions are stacked on top.
None of that is a research grant for one lettuce shed. It is a regional industrial policy budget, and CircularFarming is a small line item inside it.
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The obvious objection to putting hydroponics under panels is that hydroponics is already a controlled environment. Why bother shading it?
Because the power bill is brutal. Pumps run continuously, nutrient dosers run continuously, climate control runs continuously, and any supplemental lighting runs on top of all of it. A Chinese-Qatari team that modeled solar-assisted hydroponic farms told pv magazine back in 2021 that these systems are water-efficient but “not an energy-efficient solution.”
More recent work put actual numbers on the gap. A 2025 study in Scientific Reports compared a grid-powered hydroponic lettuce system against one running on PV and treated greywater. The solar version needed 6.14 megajoules per kilogram of lettuce. The grid version needed 14.89, and the solar setup cut carbon dioxide emissions per square meter by more than 94%.
Wire the crop straight to the array above it and a chunk of that energy problem goes away, along with the transmission losses you eat pulling the same electricity across a substation.
The second half of the pitch is agronomic rather than financial. Leafy greens hate full July sun, and a partial canopy of modules delivers a cooler, more diffuse light environment than an open field does.
That effect is well documented at this point. Raised arrays over Arizona vegetable beds measurably drop temperatures underneath, and the relationship runs both ways, since panels lose efficiency as they heat up.
Hydroponics adds a control layer on top. A nutrient bed already carries sensors reading temperature, humidity, pH, conductivity and light. Tie those readings to the array overhead and the crop can drive its own environment, calling for supplemental LEDs when the modules shade too hard and pumps when the root zone dries out.
Japanese operators have been working the same loop from the other direction, rotating panels edge-on over rice so the crop gets its light back during the growing season. Nobody has published equivalent numbers for a soil-less bed under a German array, which is roughly the point of the exercise.
The company gets described as a German family firm, which was accurate until it wasn’t.
SUNfarming was founded in 2004 in Erkner, Brandenburg by Peter Schrum and Martin Tauschke, and says it has delivered more than 700 MW across over 1,300 sites. In November 2024, I Squared Capital’s renewables platform Cube Green Energy agreed to acquire control, with the founders keeping a minority holding and staying in post. I Squared said it was targeting more than 500 million euros of deployment by 2028 against an Agri-PV pipeline approaching 2 GW.
So the entity researching lettuce beds in Cologne is majority-owned by a Miami-headquartered infrastructure investor. That is not a criticism, it is context for how fast this research is likely to turn into hardware if the numbers land.
The scale on the other side of the business makes the point. SUNfarming began construction this spring on the Steinhöfel Klimapark in Brandenburg, a 753 MWp agrivoltaic park spread across roughly 1,236 acres and eight districts, with permits in hand for the first 550 MWp and an EEG auction award covering the opening 106 MWp phase.
Here is the part the press release skips.
Germany does not let you call something a farm because you parked a goat under a solar panel. DIN SPEC 91434 sets the standard the EEG references, and it requires that agricultural production stay the primary use of the land, delivering at least 66% of a reference yield. Separately, the CAP direct payments rules say at least 85% of the area has to remain agriculturally usable for the subsidy and the tax status to survive, a threshold the federal agriculture ministry states plainly.
Those rules were written for plants in dirt. A hydroponic bed is a structure sitting on the ground, fed by pumps, growing a crop that never touches the soil beneath it.
Whether German and EU authorities treat that as agricultural use of the land, as an installation occupying the land, or as something in between is an open question, and it is the single largest variable in whether any of this pencils out. We reported how hard that 66% threshold bites when a developer has to prove it at commercial scale. Neither SUNfarming nor TH Köln has published a position on how soil-less systems are meant to clear it.
The physical constraints are not trivial either. SUNfarming builds to DIN SPEC with bifacial glass-glass modules at a minimum clearance of about 6 feet 11 inches, and its structures are specified for small tractors with a 10-foot working width. Fitting growing tanks, plumbing and a nutrient loop into that envelope without blocking the machinery is a real design problem, and steel is what kills most agrivoltaic budgets before anything else does.
The end product here is not a farm. It is a planning tool.
TH Köln is building a model-based planning, simulation and training toolbox that treats vertical indoor farm design as a multi-criteria bioeconomic optimization problem, so a developer can specify a site, a crop and an array layout and get back a system sized to match. Aquaponics is in scope alongside hydroponics. Demonstration and education sites are part of the remit, which is why the project keeps showing up at public workshops in Cologne rather than in yield reports.
That is a slower and less quotable outcome than a working lettuce farm, and it is probably the more useful one. Anybody can build a demonstrator. Handing a farmer in Brandenburg a tool that tells them whether the numbers work on their specific parcel is the thing that turns a research project into an industry.
SUNfarming has until February 2028 to produce it, a 753-megawatt construction site to keep fed, and an American infrastructure fund watching the returns. If the soil-less version clears the regulatory bar, the same company already has the land, the steel and the permits to scale it. If it doesn’t, the panels will keep making money and somebody will plant grass underneath, which is what happens on most of these sites anyway.
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ATOME PLC has signed an agreement with the dollar fund of a multilateral development bank to fund a feasibility study for a 300 MWp solar photovoltaic project near Villeta, Paraguay.
ATOME PLC, listed on the AIM market of the London Stock Exchange, has announced an agreement with the dollar fund of a multilateral development bank to support ATOME Power, its renewable energy and battery storage division. The fund has agreed to provide financial and technical support, subject to certain conditions, for a feasibility study covering a projected 300 megawatt-peak (MWp) solar photovoltaic project near ATOME’s green fertiliser plant in Villeta, Paraguay. This type of support fits into a broader global trend of solar development, similar to Gurīn Energy, which secured 379 MW of solar licences in South Korea, Recurrent Energy, which brought a 150 MW solar park online for Microsoft, and Huasun, which signed a 100 MW solar deal with Air Solution in Pakistan.
The solar project, still under review, would be built in close proximity to ATOME’s green fertiliser production site in Villeta, where the company says it has access to substantial areas of land for such development. According to ATOME, this geographic proximity would allow infrastructure to be shared and would help secure the plant’s power supply through local solar generation. The company states it wants to explore the possibility of building an industrial park structured around solar power and battery storage.
Progress on the feasibility study nonetheless remains conditional on advancing the power purchase agreement that ATOME Paraguay, the group’s local subsidiary, must negotiate. Once that agreement is concluded, ATOME Power would move forward immediately with the technical and financial study of the photovoltaic project. The company has not specified a timeline for finalising the agreement or for the effective launch of the study.
ATOME says it is encouraged by the prospect of creating an industrial hub built around solar power and battery storage, capitalising on the activities and trades generated by its green fertiliser production site. The company states it will provide a further update on the project once ATOME Paraguay’s position on the power purchase agreement is resolved.
The global solar market continues to attract financing from development banks for projects that combine renewable generation with local industry. ATOME’s Paraguayan project, if it moves forward, would add 300 MWp of photovoltaic capacity in a country where large-scale industrial solar investment remains limited.
An analysis covering 2,344 Chinese counties links large-scale photovoltaic deployment to a measurable decline in bird diversity, despite mandatory greening measures accompanying so
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New Zealand’s solar capacity reached 830 MW by the end of 2025, according to a report released by the country’s Ministry of Business, Innovation & Employment (MBIE).
MBIE’s Energy in New Zealand 2026 report says the country’s solar capacity increased by 52% during 2025, increasing from 545 MW at the start of the year.
The growth is attributed largely to the development of New Zealand’s utility-scale solar market, including the country’s first solar park to be connected directly to the national transmission grid. A total seven utility-scale solar plants of 9 MW or larger were switched on in New Zealand last year, the report says.
New Zealand’s cumulative solar capacity now likely stands in excess of 1 GW. Additional utility-scale plants have already been switched on in 2026, including the 150 MW Tauhei Solar Farm and 38 MW Omeheu Solar Farm.
MBIE’s report adds total electricity generation capacity from renewables surpassed 9 GW in 2025, led by hydro and geothermal sources. Solar made up 9.1% of this figure, compared to 1.9% in 2020.
The share of renewables in New Zealand’s primary energy supply increased from 45.6% in 2024 to a record 47.7% last year. In 2025, 88.5% of electricity in New Zealand was generated from renewable sources, compared to 85.5% the year prior.
Energy consumption from renewable sources increased to a record 32% of total consumption, which MBIE’s report says reflects both an increase in renewable supply and lower industrial demand for energy, which is mainly met from non-renewable sources. Elsewhere, coal consumption dropped to record lows, while natural gas consumption fell to its lowest level since 2008.
MBIE says solar generation is expected to continue increasing over the next few years, with further grid-connected solar plants currently under construction or in planning.
An investment pipeline published by the country’s Electricity Authority shows over 1.7 GW of new capacity from committed projects expected to come online over the next three years, with solar accounting for 930 MW of the total. Renewable energy sources account for 94% of the total planned capacity, with battery energy storage accounting for the remaining 6%.
The utility-scale expansion comes as the government also seeks to encourage smaller-scale solar installations. Earlier this week, it backed plans to legalize plug-in solar for households as part of efforts to make the country’s rules governing the installation or small- and medium-sized solar systems “the simplest in the developed world.”
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India added 34 GW DC of solar capacity in H1 2026, up 38% YoY, putting it on track to exceed 50 GW DC for the year, says Wood Mackenzie 
Analysts flag limited availability of ALMM List-II-enlisted cells that could slow project development in H2 2026 
The research firm expects utility-scale solar system prices to rise 20% by Q4 2026 as cell supply constraints tighten 
India added 34 GW DC of solar PV capacity in H1 2026, 38% more than in the same period last year, putting the country on course for its biggest annual solar installation year, according to Wood Mackenzie. The research firm expects full-year solar additions to exceed 50 GW DC, surpassing the previous record of 49 GW DC set in 2025. 
However, the rapid buildout is pressuring the domestic cell supply chain, particularly as the Approved List of Models and Manufacturers-II (ALMM-II) mandate took effect on June 1, 2026 (see India Brings ALMM List-II For Solar Cells Into Force). 
The 34 GW DC added during H1 2026 reflected a concentrated effort by developers to commission projects before ALMM-II came into effect. Wood Mackenzie says that the installation push was also supported by changes to inter-state transmission charge waivers that fell from 75% to 50% for projects commissioned from July 2026 and scheduled to be phased out completely after July 2028.  
The lack of adequate solar cell capacity enlisted under ALMM List-II is likely to hamper project development in H2 2026, according to Wood Mackenzie. As cell supply constraints tighten the market, utility-scale system prices are projected to rise 20% by Q4 2026. 
Even as new cell capacity comes online, Wood Mackenzie expects insufficient utilization to keep supply below demand in 2027. The research firm expects India’s cell production to reach 29 GW in 2027, still 21 GW short of average annual module demand of 50 GW. As a result, system prices are forecast to decline by just 3% between Q4 2026 and Q4 2027. 
“India’s ALMM-II mandate is a bold step toward building a fully integrated domestic solar supply chain, but cell manufacturing capacity has simply not kept pace with modules,” said Sureet Singh, Research Analyst at Wood Mackenzie. 
He adds, “The near-term cost impact is unavoidable, and developers will need to navigate a difficult transition period before prices stabilise.” 
Yet, Singh believes MNRE’s exemptions for net-metering and open-access projects through December 31, 2026 could provide some upside to installations (see MNRE Grants ALMM Relief For Net-Metering, Open Access). 
With Chinese solar cell supply to India restricted due to the ALMM List-II, cell imports have shifted to Southeast Asia. Wood Mackenzie said sourcing has shifted toward Southeast Asia, with Indonesian cell imports nearly tripling in early 2026.  
Within 5M 2026, India imported 20 GW of cells and 5 GW of wafers. Wafer imports increased 86% year-on-year (YoY) as domestic manufacturers sought feedstock for cell production. The research firm warned that any delay in commissioning the 14 GW of cell capacity currently under construction could increase import dependence and push prices above its current forecast. 
India is expected to add another 130 GW of cell capacity by 2029. This would require a 49% compound annual growth rate (CAGR) from the 2026 full-build baseline of 88 GW. 
“Prices are expected to stabilise through 2029 as additional cell capacity comes online, but the transition will require policy consistency and timely execution by manufacturers,” said Mathew Thomas, Research Analyst, Wood Mackenzie. 
India is set to follow List-II with the planned ALMM-III, scheduled for June 2028, which will extend domestic-content requirements to solar wafers (see India To Enforce ALMM List-III For Ingots, Wafers On June 1, 2028). 
TaiyangNews 2024

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At peak daylight in the Mojave Desert, the $2.2 billion Ivanpah Solar Electric Generating System looks like an engineering triumph: three 450-foot towers illuminated by thousands of gleaming mirrors.
Yet beneath that glittering facade lies one of California’s most expensive clean energy dilemmas. Utilities want to abandon the troubled 392-megawatt facility, but state regulators refuse to let them walk away.
Now, four researchers from the National Renewable Energy Laboratory have devised a turnaround strategy that could rescue the site from premature closure.
Pacific Gas & Electric and Southern California Edison are seeking to exit their 25-year power purchase agreements early. The utilities cite chronic underperformance and operating costs that no longer make financial sense.
However, the California Public Utilities Commission has repeatedly rejected their exit requests.
California mandates 60% renewable electricity by 2030, and taking 392 megawatts offline creates a major policy setback. Regulators also point to hundreds of millions of dollars in transmission infrastructure tied to Ivanpah that would be wasted.
Furthermore, replacing Ivanpah with new solar projects is hindered by equipment tariffs, tax credit uncertainties, and lengthy permitting delays.
Ivanpah’s central vulnerability stems from a fundamental design flaw: a direct-steam system built without thermal energy storage.
Since opening in 2014, the plant has delivered only 70% to 80% of its expected annual generation. Passing clouds frequently halt the steam turbines, forcing operators to burn natural gas to restart the power cycle.
Without storage, Ivanpah must sell electricity during midday hours when cheap photovoltaic solar floods California’s grid, pushing spot prices down to zero or negative levels.
Yet one critical component performed exceptionally well: the field of 173,500 tracking mirrors achieved 92% to 94% operational availability. The solar collection field was never the problem; the failure was how collected heat was processed and monetized.
To break the deadlock, researchers evaluated repurposing Ivanpah’s existing infrastructure rather than bulldozing it. The plan retains the high-performing mirror field and central towers while replacing the outdated direct-steam boilers.
By installing a modern molten-salt receiver, the facility can capture high-temperature solar energy and transfer it into thermal storage. This system connects the mirror array to a two-tank molten-salt system capable of storing 12 hours of energy.
Instead of dumping power during midday price troughs, the plant can hold its heat and generate electricity when grid demand peaks after dark.
When Ivanpah was built, midday solar power still commanded strong market prices. As low-cost solar panels saturated global grids, international developers adapted by making molten-salt thermal storage standard on central tower projects.
Global energy markets in China, Morocco, and Israel quickly built standardized 100-megawatt solar towers paired with thermal storage.
Firms like China Three Gorges Renewables and CNNC HuiNeng gained extensive experience operating large-scale thermal storage systems. Ivanpah remained isolated as a first-generation relic, incapable of shifting generation to match evening price spikes.
This operational gap left the Mojave facility financially stranded while international peers demonstrated the profitability of dispatchable solar thermal energy.
Here is the final breakthrough revealed by the researchers’ financial modeling: retrofitting Ivanpah transforms a failing asset into a high-yield power plant.
Assuming the existing towers and mirror arrays are treated as sunk costs, the upgraded facility achieves a 30% higher internal rate of return than Ivanpah’s historical baseline. At 2024 grid schedules, the retrofitted plant could deliver dispatchable power at a competitive rate as low as 6.99 cents per kilowatt-hour.
This conversion proves that legacy clean energy assets retain immense salvage value when adapted to modern market conditions.
By converting a stranded direct-steam plant into a dispatchable 12-hour thermal storage giant, four researchers have handed California a blueprint to save its Mojave Desert facility.
Kelly is an experienced writer with 15 years of experience exploring the big stories that shape our world, from tech breakthroughs and space exploration to climate, energy, and the fascinating quirks of science. She has a talent for turning complex ideas into sharp, memorable insights that stay with readers long after they’ve finished reading.
Kelly is an experienced writer with 15 years of experience exploring the big stories that shape our world, from tech breakthroughs and space exploration to climate, energy, and the fascinating quirks of science. She has a talent for turning complex ideas into sharp, memorable insights that stay with readers long after they’ve finished reading.
Kelly is an experienced writer with 15 years of experience exploring the big stories that shape our world, from tech breakthroughs and space exploration to climate, energy, and the fascinating quirks of science. She has a talent for turning complex ideas into sharp, memorable insights that stay with readers long after they’ve finished reading.

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Rompetrol will build a 4.8 MW photovoltaic power plant at the Vega Ploiești Refinery, with an investment of 27 million lei  Informat.ro
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The TaiyangNews PV Price Index staged a partial turnaround in Calendar Week 33, with wafer and cell prices recording increases of 9.1% to 31.0% week-on-week (WoW).
The polysilicon segment was unchanged for the third consecutive week.
The wafer segment recorded sizable increases WoW, ranging from 9.1% to 12.5%.
The cell category saw its largest WoW increases in recent weeks, with prices rising by 22.0% to 31.0%. Note that China’s SAMR recently urged solar PV companies to strengthen price compliance and shift competition from price to quality (see Chinese Regulator Issues Guidance Against ‘Predatory’ PV Pricing).
Among modules, TOPCon bifacial 182 mm prices increased by 0.8%, while 210 mm 60-cell (630-655W) prices rose by 1.5% WoW.
The two solar glass variants have seen no price changes since CW17.
The TaiyangNews PV Price Index appears to have stabilized over the past 3 weeks, with the latest increases in wafers and cells suggesting a possible turnaround in these segments, coinciding with China’s efforts to curb unfair price competition.
Year-to-date (YtD), the polysilicon segment has lost more than a third of its value. Wafers and cells have significantly clawed back their earlier declines, with 2 cell types turning green this week. Solar glass prices are down between 7.5% and 14.8%. Among modules, only 1 module type remains in the red YtD.
The data refers to average product prices in China. The data was collected by Chinese market research firm Gessey PV Consulting.
Disclaimer: TaiyangNews does not guarantee reliability, accuracy or completeness of this price index’ content. TaiyangNews does not accept responsibility or liability for any errors in this work.
TaiyangNews 2024

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Aisin wins NEDO backing for 500mm perovskite solar modules  International Business Times
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JA Powers Fisher & Paykel Healthcare’s Green Transition with New Zealand’s Largest Rooftop PV System

JA Powers Fisher & Paykel Healthcare’s Green Transition with New Zealand’s Largest Rooftop PV System
BEIJING, Aug. 19, 2026 /PRNewswire/ — Recently, JA powered Fisher & Paykel Healthcare’s step toward a more ecosystem-friendly future by supplying New Zealand’s largest rooftop photovoltaic (PV) power station in Auckland. The 5.3 MWp system, featuring JA’s high-efficiency modules from their deep blue series, is helping transform healthcare manufacturing toward greener, lower-carbon practices.

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Indian solar manufacturer Websol Energy System has started upgrading an existing monocrystalline PERC cell line to TOPCon technology, with the project expected to be completed by March 2027.
The company is converting a 600 MW mono PERC line into a 750 MW TOPCon line at its existing facility. The upgrade will increase Websol’s total cell manufacturing capacity from 1.2 GW to approximately 1.35 GW. Once completed, TOPCon will account for around 55% of its cell capacity.
The upgraded line is expected to achieve cell efficiencies of around 25%.
Websol is also targeting further reductions in silver consumption as it transitions to TOPCon technology. TOPCon cells, which now dominate global crystalline silicon production, consume more silver than earlier technologies such as PERC, making them more sensitive to silver price volatility.
The company said it reduced silver consumption by 20% in the 2025-26 financial year and is targeting a further 10% reduction. Over the longer term, Websol is evaluating alternative metallization technologies to reduce its reliance on silver.
Websol is also planning a 4 GW integrated cell and module manufacturing facility, which will be developed in phases to mitigate the risks associated with technological changes in the solar industry.
The company plans to locate the expansion near its existing operations in West Bengal, benefiting from access to an established supply base and skilled workforce while potentially shortening the time required to bring new capacity online.
“West Bengal’s recent push toward greater industrialization, including the proposed new industrial policy, easier access to industrial land and a stronger focus on attracting manufacturing investment is encouraging for companies like ours, which already have an operating base here. So, we see West Bengal not merely as the location of our existing plant but as a natural place to consider for the capacity we build next,” the company said.
Websol has partnered with Linton Crystal Technologies to provide equipment and technology support for its planned greenfield ingot and wafer manufacturing facility.
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A wave of new heterojunction (HJT) solar cell and module manufacturing announcements in the US is highlighting the rapid shift in PV technology as the country continues to increase its domestic solar manufacturing supply chain. With manufacturers increasingly looking beyond p-type PERC towards n-type technologies, the US cell manufacturing landscape is being reshaped by a combination of technology transitions, trade measures and the push for greater domestic content.
Against that backdrop, ES Foundry is taking a more cautious approach. The company is betting on established PERC technology as the foundation for its US cell manufacturing strategy today, while preparing to transition to a next-generation n-type technology as market conditions, intellectual property considerations and supply-chain availability become clearer.
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ES Foundry CEO Alex Zhu tells PV Tech Premium that the company’s strategy is centred on delivering commercially bankable US-made cells today, even as it prepares to transition from crystalline bifacial p-type passivated emitter rear contact (PERC) to a next-generation n-type technology.
The company recently completed a 2GW expansion of its solar cell manufacturing capacity in Greenwood, South Carolina, taking its total capacity to 3GW as it seeks to establish itself as one of the few large-scale crystalline silicon cell manufacturers producing and shipping product in the US.
Es Foundry began operations with its first 1GW of capacity in 2025. According to Zhu, the company expects to have the expanded capacity fully ramped by October.
For him, however, the significance of the expansion extends beyond the headline capacity figure. He argues that ES Foundry’s differentiation lies in having moved from announcements to actual production.
“In terms of actual production, we are the largest crystalline solar cell manufacturer in the US,” Zhu tells PV Tech Premium.
He contrasts this approach with what he describes as a US solar manufacturing landscape characterised by numerous large announcements, some of which have not translated into operating capacity.
That focus on delivering product is also central to ES Foundry’s technology strategy.
Last year, energy market analyst Clean Energy Associates (CEA) said PERC solar PV technology was “all but obsolete” in Europe, with n-type tunnel oxide passivated contact (TOPCon), heterojunction (HJT) and back contact (BC) technologies having almost entirely displaced it in “many international markets”, driven by China’s manufacturing scale, lower prices and higher efficiency.
Yet while much of the global industry has moved on, US cell manufacturer ES Foundry is taking a different approach, betting on PERC as the foundation of its domestic manufacturing strategy — for now.
Zhu acknowledges that PERC does not offer the same efficiency potential as newer cell technologies. But he argues that efficiency is only one part of the equation for a new US manufacturing operation.
“The reason we chose PERC is that it is very reliable and has a robust process window,” he notes.
For ES Foundry, that maturity provides two important advantages. The first is bankability. Financial institutions and customers are already familiar with PERC, while some newer technologies have a shorter track record in commercial manufacturing.
“The whole banking industry are familiar with PERC,” Zhu says. “Whereas some of the new technologies in US have not been fully tested.”
The second advantage is manufacturing. The US is rebuilding a solar manufacturing workforce after years in which much of the global cell production base migrated to Asia. Zhu says the shortage of experienced engineers, operators and technicians makes manufacturing a mature technology with a relatively forgiving process window particularly valuable.
“Using PERC as a starting point is very good for us to train the local labour force without cause a significant loss of efficiency or reliability.”
PERC is therefore the starting point rather than the destination. Zhu says ES Foundry will eventually move from p-type to n-type technology, but the company has not yet decided which specific n-type architecture it will adopt.
“We will move to n-type technology. However, we haven’t decided which n-type technology we will go with because this depends on multiple things like IP issues, the supply chain, and equipment availability.”
For ES Foundry, the choice of technology is also an IP decision. Recent TOPCon disputes involving First Solar, JinkoSolar, Trina Solar, Maxeon and Canadian Solar underline the litigation risks facing manufacturers adopting the technology in the US.
Earlier this month, US President Donald Trump introduced a 15% tariff on imports of polysilicon and its derivatives, alongside minimum import prices, under Section 232, with the measures set to take effect on 4 December 2026.
Experts, who recently spoke with PV Tech Premium, said the Section 232 measures could support established US manufacturers and upstream investment, but raise solar costs, weaken demand and potentially deter new capacity, a tension echoed by Zhu. He says the measures on polysilicon and related upstream materials will significantly increase ES Foundry’s wafer costs.
“Our current wafer cost is, for example, from 4 cents to 7 cents imported from overseas. And after that, our cost will increase to like 15 cents plus 2 cents tariffs. That’s a significant increase in our cost. And of course, that will eventually increase our price to ship to our customers. Anytime you increase the price, a customer will not like it, and your demand will reduce,” the CEO emphasises.
Having said that, Zhu says the higher cost of imported wafers could ultimately be offset by stronger demand for domestic-content modules as the price gap with imported products narrows.
For ES Foundry, therefore, Section 232 presents a balancing act: higher input costs on one side, but potentially stronger demand for its US-made cells on the other.
Zhu says domestic-content modules can benefit from an additional 10% investment tax credit, potentially reducing the overall cost of a solar project even where the domestic-content module itself carries a higher upfront price.
“Even a domestic content module by itself is more expensive, but when you’re calculating into the whole formula, the total project cost will reduce,” he says.
Zhu also points to the rapid growth of solar projects associated with AI data centres as another source of demand.
“We see so many more project developers selling their projects to support the growth of AI data centres. At the same time, those customers also require domestic content because that will reduce the overall costs.”
The opportunity extends beyond cells. As domestic-content requirements increase, Zhu expects module manufacturers and their suppliers to look increasingly at other components, including junction boxes, EVA, ribbons and frames, to maximise the domestic contribution of their products.
The One Big Beautiful Bill Act (OBBBA) and evolving trade measures are therefore becoming important parts of the commercial landscape in which ES Foundry operates.
For ES Foundry, scaling US cell manufacturing goes beyond adding capacity: the company still faces gaps in both its upstream supply chain and local workforce.
The company currently sources Chinese and non-Chinese polysilicon, with wafers produced in Southeast Asia, while US-made P-type wafers are not yet part of its supply chain.
For now, however, the company is focused on ramping its cell operations rather than pursuing backward integration into wafer manufacturing or forward integration into modules.
The workforce presents another challenge. Zhu says ES Foundry is training locally but continues to see a significant skills gap, prompting partnerships with MIT’s Initiative for New Manufacturing and a local community college in Greenwood.
“We’re doing a lot of training to train our local force, but there’s a significant gap,” he says. The training programme is intended to accelerate the development of workers capable of supporting both the current factory and future manufacturing expansion.
In the near term, ES Foundry appears confident that demand will support its existing 3GW annual nameplate capacity, with off-take agreements extending through 2028.
Zhu acknowledges that higher interest rates and interconnection delays could weigh on US solar demand, but says customers can shift delayed projects elsewhere.
“Most of our customers have multiple projects on hand, so even if some are delayed, they can easily shift to other projects.”
For ES Foundry, the immediate priority is therefore clear: establish reliable cell production while building the supply chain and workforce needed for its next phase of growth.

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Egypt has approved the Nefer Minya project that will pair 1 GW of solar capacity with a 600 MWh battery system 
AIKO had previously announced its selection as the sole module supplier for the solar project 
The project is being developed by Infinity Power and Hassan Allam Utilities in Minya 
Egypt has approved the $750 million Nefer Minya project, a planned 1 GW solar power plant paired with a 600 MWh battery energy storage system (BESS) in Minya Governorate. 
The Egyptian Cabinet has granted the solar-plus-storage project a Golden License that requires approval from the Council of Ministers, helping fast-track investment. 
Infinity Power and Hassan Allam Utilities are developing the project. The company’s website says the BESS component is planned to provide two hours of energy shifting to the Egyptian grid. The project’s environmental and social assessments have been completed, Infinity Power said. 
It is scheduled for completion by September 30, 2027. It will create jobs for around 2,500 engineers, technicians, and workers during the construction phase. According to the Egyptian Cabinet, the project is designed to support environmental sustainability, preserve natural resources, and reduce carbon emissions by 1 million tons annually. 
In June 2026, AIKO announced that it had been selected as the sole PV module supplier for the project, which Infinity Power says will have 1.2 GW installed capacity. AIKO said the 1.2 GW solar facility would use its all-back-contact (ABC) modules. Once operational, it will supply electricity to about 1.4 million homes. 
The project is backed by financing from the European Bank for Reconstruction and Development (EBRD). According to the bank, “The Project will support the Egyptian Government in achieving its renewable energy target and will be among the first batch of BESS projects in the country, developed under the 10 GW renewables target set under the Bank-led Energy Pillar of the NWFE initiative.” 
TaiyangNews 2024

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MNRE mandates domestic storage of inverter data for PM Surya Ghar projects
August 21, 2026
Follow Mercom India on WhatsApp for exclusive updates on clean energy news and insights
India added nearly 6 GW of solar open access capacity in the first half (1H) of the calendar year 2026, up 42% year-over-year (YoY) compared to 4 GW, according to Mercom India’s newly released Q2 2026 India Solar Open Access Market Report.
The Ministry of New and Renewable Energy (MNRE) directed inverter manufacturers supplying rooftop solar systems under the PM Surya Ghar: Muft Bijli Yojana to ensure that inverter-level data and associated monitoring and control servers are located exclusively within India.
The government recently told Parliament that over 5,400 power sector cases are pending before electricity sector regulators and the courts. Cases involving the Ministry of Power numbered 1,303, while 2,911 and 1,193 petitions are pending before the Appellate Tribunal for Electricity and the Central Electricity Regulatory Commission, respectively, bringing the total to 5,407 as of June 30, 2026.
The Maharashtra Electricity Regulatory Commission allowed Maharashtra State Electricity Distribution Company to implement the utility-led aggregation model for installing rooftop solar systems for 211,206 low-income households in Maharashtra.
The Uttarakhand Electricity Regulatory Commission (UERC) proposed reducing the tolerance to ±5% for solar and hybrid projects and to ±10% for wind projects, aligning with the Central Electricity Regulatory Commission’s revised deviations settlement tolerance bands.
UERC rejected a petition seeking reconsideration of the trading margins prescribed for solar and standalone battery storage projects. The Commission noted that the petitioner, UJVN, had not identified any error in its January 6, 2026, order and was raising an issue that had already been considered and decided.
For many industrial consumers with high power requirements, the lack of adequate rooftop space often restricts the benefits they can harness from on-site solar projects. With solar parks, such companies can set up larger projects off-site and use the generated power to reduce their electricity costs. Harmony Plastics and Plasti Weave Industries, part of the Mewar Polytex Group, have installed 2.5 MW and 3 MW solar projects, respectively, at the SafEarth UGVCL-1 solar park in Himatnagar, Gujarat.
NTPC Renewable Energy issued a tender to install wind turbine generators for an interstate transmission system -connected wind energy project with a nominal capacity of 600 MW, comprising 200 WTGs in Anantapur, Andhra Pradesh. Bids must be submitted by September 15, 2026. Bids will be opened on the same day.
NLC India invited bids to arrange 1,500 acres of land through outright purchase for solar projects in Tamil Nadu. The last date to submit bids is September 21, 2026. Bids will be opened on the same day.
Tata Power-D, the distribution arm of Tata Power Company, invited bids to procure 50MW/100MWh (1 cycle) of battery energy storage capacity for a 15-year period from a grid-connected inter-state project in Rajasthan. The last date to submit bids is September 15, 2026. Bids will be opened on the same day.
Independent power producer AMPIN Energy Transition achieved financial closure for a $195 million project finance facility for a power purchase agreement-backed 100 MW wind-solar project with battery energy storage systems in Andhra Pradesh.
Mahindra Susten, the clean-tech arm of the Mahindra Group, achieved financial closure for its 150.8 MW hybrid renewable energy project being developed under the group captive offtake arrangement in Maharashtra. The project secured financing of ₹8.75 billion (~$91.51 million) from Export Import Bank of India under its Sustainable Finance Program.
Renewable energy solutions provider Canadian Solar announced the resolution of the remaining U.S. patent litigation brought against it by Maxeon Solar Technology over TOPCon solar cell technology. A U.S. federal district court dismissed Maxeon’s patent infringement lawsuit against Canadian Solar with prejudice.
Mercom Staff
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Silver makes up roughly 0.5% of a solar cell’s mass, yet accounts for 47% of its recycling value, according to a May 2026 research paper on PV recycling in Science Bulletin – an imbalance that dictates much of how recyclers approach end-of-life panels.
SPR, whose North Carolina operation grew out of a two-decade-old electronics recycling company, has spent years developing its solar recycling process around those economic realities. With a key solar recycling certification deadline looming in January 2027, CEO Brett Henderson spoke with pv magazine about where SPR stands, how the company thinks about recovery rates, and what he is seeing in reuse markets.
pv magazine: Where does SPR’s North Carolina facility stand with regard to R2V3 Appendix G? Are you fully certified, mid-audit, or working toward a target date ahead of the January 2027 deadline?
Brett Henderson: SPR was formed out of a parent company that was an R2V3 and e-steward certified electronics recycler in business for about two decades … My concerns about that in the solar industry is solar modules are basically a singular line item … they’re more or less negative value to process because it’s mostly glass composition. So our concerns with the R2V3 on the solar side, even though we fully support it and have been abiding by it for about 16 years on the parent company side, is that the Appendix G still allows the recycling to be outsourced while someone carries that certification … the glass needs to be recovered cleanly, not commingled and recovered by that certified company in-house.
At the moment, we’re kind of to be determined on the R2V3 in our North Carolina facility … So our compliance team, by the direction of myself, is kind of basically we have up until 2027 to kind of decide if we want to, you know, get it to that appendix.
If SPR decides not to pursue Appendix G, what are the implications – for SPR and for the industry?
If it’s a standalone solar company and there’s no asset owners requiring it for an RFP or requiring it to be onboarded as a vendor, there isn’t really any pressure to a standalone solar company to get the Appendix G correct.
Our North Carolina facility, we’re building standalone solar building. That would be done before that deadline. So there won’t be any – having to go by the Appendix G since it’s a separate company isn’t something that’s going to happen … there is a good bit of them that are on this committee that’s been working in the background for 18 months to make this gold standard through the major trade association in the US. It seems the pulse of the committee as a whole is ‘let’s make a standard specific for this industry,’ not just an appendix to it.
Do you anticipate any impact on recycling volume if a meaningful share of the industry misses this deadline?
No, because again, we’re not manufacturing a product. We’re demanufacturing a product … None of the major US EPCs, O&Ms, utilities are requiring this standard. So if somebody does not hold this standard at the moment, it’s not going to affect throughput recycling in the US market, none of the above.
In a recent IEA-PVPS Task 12 report on recovery rates and process, the figures cited for SPR are 99% copper recovery and up to 98% silicon recovery. Are these numbers from independent third-party testing, or self-reported?
It’s a little bit of a hybrid of both. So IEA did not require us … to send samples off to them or to a third party lab for them to confirm. But when they were doing their research, their questionnaires, their interviews, understanding our processes, they highly recommended and wanted to see some third-party lab results … yes, we do have tests behind that, but the IAE specifically didn’t … have those samples sent off or any type of lab reporting on their end.
How does SPR mechanically separate silicon, glass, and other materials during processing?
What gets conflated a lot on the mechanical side is taking full solar panels, batch feeding them through a shredder and shredding them down … as a whole, and then trying to find ways to separate the different type of commodities within that. That type of mechanical processing is always going to lead to contaminated products.
What we have at SPR is mostly a mechanical process … what we’re doing is we are systematically removing each commodity … This is where we’ve already had $12 million of investment this year alone on some new glass technology … How do you take the layers, encapsulated glass and silicon and backsheet and cleanly separate them? Because if your glass is contaminated with plastics and silicon and silver and other metals, it’s not going to be able to be actually consumed at volume and at scale in different glass manufacturing.
Is SPR profitable on recycling alone, or are other revenue lines important?
We’re profitable recycling alone under the industry … with the asset owners paying some level of a recycling fee … That fee has came down tremendously since we started in 2018, like almost 80% at this point, and that’s mainly because we keep investing in two things. We keep investing in technology to get the cleanest separation … but also the major driving cost force in the industry, specifically in the US that’s such a large geographical footprint, is transportation.
What’s the biggest cost driver, and which costs do you expect to fall fastest as volume scales toward the end of the decade?
Definitely the cost driver in the US market is going to be transportation … So it’s quite important that we continuously build out our owned and operated distributed network of recycling facilities. The biggest opportunities for costing to come down even further is going to be more clean glass hitting the market in the United States and it being able to stay more regional … I think the biggest driver is just going to be in any industry, in any recycling industry, volume is king.
You mentioned solar reuse as a competing force in the industry. What’s happening there?
What’s going on at the moment globally is there’s quite a bit of greenwashing happening on this reuse side … what’s happening globally is aluminum is trading high enough now that you could take panels for free from acid owners, say they’re going to be reused, and a lot of panels are starting to get shipped overseas, whether that’s Southeast Asia, whether it’s the west coast of Africa. We probably get pinged maybe 10 to 15 times a week as one of the global solar recycling brands from companies that say that they want to buy reused solar panels. Here’s the issue with it.
The reuse market is nowhere near any level of scalability. And the reason for that … is there’s major regulations about connecting used panels back to the grid … In the US specifically, the UL rating is no longer valid once that panel becomes used … You can load about 500 to 550 of these modules on a container. A company could absorb the shipping costs … and have limited to no labor costs … and what’s happening is this is all under the guise of ‘hey these panels are going to be reused elsewhere.’
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The new issue of pv magazine Global is out now!
Available in print and digital – get your copy today!
A two-day conference in Austin, Texas, bringing together leaders in US solar manufacturing, equipment specification, and factory execution.
Entries open in seven categories: Modules, Inverters, BoS, BESS, Manufacturing, Sustainability, Projects.
April 01 – August 31, 2026
Tuesday, August 25, 2026
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pv magazine USA hosts its third multi-day virtual event on advancing U.S. solar and energy storage markets, covering financing, supply chains, and distributed energy’s role in grid resilience.

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JinkoSolar has officially launched its “Sunny 365” smart PV-storage system—a solution tailored for the manufacturing industry. The solution integrates high-efficiency photovoltaics, smart energy storage and AI-driven dispatch to help manufacturing businesses in sectors including textiles, cement, steel, home appliances, home textiles, apparel, electronics, hardware, machinery and construction vehicles—a complete energy system ranging from on-site generation and self-consumption of green electricity to precise demand management and emergency backup power, thereby reshaping the energy infrastructure of industrial production.
As photovoltaic and energy storage applications become increasingly widespread, more and more manufacturing companies are utilizing idle rooftop space to build their own dedicated  projects. However, they have long faced four major challenges: a lack of standardization in product selection, difficulties in matching PV and storage systems, high coordination costs and cumbersome post-installation O&M. Procuring modules, storage systems and other software and hardware separately, while integrating technical resources from multiple vendors, results in lengthy cycles and significant investment, keeping the barriers to implementing projects high for small and medium-sized manufacturers.
The “Sunny 365” smart PV-storage system series—specifically the manufacturing PV-storage solution—directly addresses these industry challenges by providing an integrated PV + energy storage + smart management solution, going beyond single-component PV or  storage configurations. Centered around the Tiger Neo 3.0 high-efficiency PV modules and the SunGiga G2 C&I liquid-cooled ESS, it integrates AI-powered intelligent dispatch algorithms with the JinkoCloud platform to provide the manufacturing sector with a scenario-based, standardized and replicable one-stop energy solution.
To address core challenges faced by manufacturing plants—such as high electricity costs, stringent requirements for continuous production and significant load fluctuations—the solution offers standardized capacity configuration models covering three major industries.
The plants are high-voltage dedicated transformer users operating at 10 kV or higher, with production loads significantly higher during daytime and on weekdays than at night or on holidays. “Roof-mounted PV + consumer-side energy storage” is one of the most economically viable scenarios, featuring a high proportion of self-consumed PV power, while energy storage enables peak-valley arbitrage, demand response and distribution capacity relief.
Key challenges in electricity consumption include the high proportion of electricity costs in manufacturing expenses, as well as the significant impact of peak-hour and super-peak electricity rates on production costs. Power rationing or load shedding disrupts continuous production and production line downtime losses may far exceed the electricity costs themselves; short-term load spikes potentially leading to insufficient transformer capacity, with capacity expansion involving long lead times and high investment costs.
High-Efficiency solar-to-storage products: Reducing costs and boosting efficiency in the manufacturing industry
1. Feihu 3 Modules:
As a high-efficiency module product, the Feihu 3 features core advantages specifically designed for manufacturing rooftops – high power output, ultra-high bifaciality, excellent temperature coefficient, extremely low linear degradation and exceptional low-irradiance performance on cloudy or rainy days, and at dawn and dusk.
2. SunGiga G2 ESS: Quadruple safety protection
The ESS positions robust safety as its core competitive advantage, comprising material-level thermal isolation, electrical-level armour, multi-sensor fusion for rapid fire suppression and full-stack early warning.
One-Stop Full Lifecycle Service
Adhering to the service philosophy of “One Partnership, Complete Peace of Mind,” Jinko provides one-stop solutions covering the entire project lifecycle, including One-Stop solution design, One-Stop warranty and One-Stop service.
1. Textile Manufacturing Model
Standardized PV and Energy Storage Installation Capacity Design:
PV Capacity: 15 MWp of rooftop and carport PV, assuming full coverage at 0.12–0.16 kWp/m² on rooftops; approximately 100,000–120,000 m² of usable rooftop area is required, with an annual electricity generation of 16.5 million kWh.
Energy Storage Capacity: 1.5 MW/3 MWh (can be configured to cover 15%–30% of peak load).
Control System: An EMS is configured to integrate PV, energy storage, main transformer loads, production schedules and time-of-use electricity rates to achieve demand response.
2. Cement Plant Model
Standardized PV and Energy Storage Capacity Design:
PV Capacity: 60 MWp (ground-mounted PV project, annual electricity generation of 66 million kWh)
Energy Storage Capacity: 10 MW/20 MWh
Control System: The EMS integrates PV, energy storage, main transformer loads, production schedules and time-of-use electricity rates to achieve demand response.
3. Steel Mill Model
Standardized PV and Energy Storage Capacity Design:
PV Capacity: 100 MWp (rooftop PV; PV capacity accounts for approximately 40%–60% of the load)
Energy Storage Capacity: 150 MW/300 MWh (Energy storage capacity accounts for approximately 60%–80% of the load; it exceeds the PV installed capacity and is used to smooth load fluctuations, perform peak shaving and valley filling and support the microgrid)
Control System: The EMS integrates PV, energy storage, main transformer loads, production schedules, and time-of-use electricity rates to achieve demand response.
The “Sunny 365” manufacturing solar-storage solution provides factory owners with end-to-end standardized services—from equipment selection and system configuration to intelligent O&M. As the use of green electricity becomes a cost-saving measure across all industries and a mandatory compliance requirement, industrial and commercial organisations must keep pace with innovations in the three key areas of photovoltaics, energy storage and AI applications. The Sunny 365 system offers a one-stop solution—a self-sustaining tool that generates sustainable returns over the long term. It provides long-duration, intelligent and stable power supply, while enabling peak-valley arbitrage with surplus electricity, helping manufacturers reduce costs, improve efficiency and achieve a green transition under the electricity market mechanism.

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Indonesia’s renewable energy ambitions require structural change  East Asia Forum
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Germany’s Federal Network Agency (Bundesnetzagentur) has awarded 2,135 MW of ground-mounted solar PV capacity in its latest auction, which closed on 1 July 2026. (Bundesnetzagentur press release, 18/08/2026). The tender, which was launched for a target volume of 2.13 GW, was oversubscribed, attracting 401 bids for a combined 3.17 GW, of which 261 bids were successful. The prices of successful bids ranged from EUR4.38c/kWh to EUR4.97c/kWh, while the average award price reached EUR4.79c/kWh.
Bavaria secured the largest share of awarded capacity with 429 MW across 75 projects, followed by Baden-Württemberg (266 MW), Rhineland-Palatinate (239 MW), North Rhine-Westphalia (233 MW) and Lower Saxony (225 MW). The next auction for ground-mounted solar PV projects is scheduled to close on 1 December 2026.
In the previous auction round held in August 2025, German authorities allocated 2.3 GW, with awarded prices ranging from EUR4c/kWh to EUR6c/kWh (average price of EUR4.94c/kWh).
Germany’s solar installed capacity exceeded 106 GW in 2025, representing almost 40% of its total installed capacity (Enerdata’s Global Energy Research).
Discover our very detailed and regularly updated RES auctions database with worldwide coverage and a technical focus backed by academic research.
With our renewable energies auctions service you will be able to monitor auctions at a global level. Its (expanding) scope notably includes all major G20 countries and offers an especially fine tracking on Europe and South America.
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South Korea picks first 86 villages for solar co-ops that let residents share profits  Yahoo
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With about 3,000 hours of sunshine a year, Malta is ideally placed to harness the sun’s energy. But its scorching summers, salty sea air and occasional Saharan dust storms also make it one of Europe’s toughest environments for solar panels.
For Dr Brian Azzopardi, a renewable energy researcher from Malta, those challenging conditions present a unique opportunity. If solar panels can withstand the island’s climate, they should perform well almost anywhere in Europe. 
Azzopardi is the chair of the Foundation for Innovation and Research – Malta, an organisation he helped establish to bridge the gap between academic research and industry. 
For the past three years, he has been leading an EU-funded research initiative called PROMISE that looked at new ways to improve the monitoring, maintenance and reliability of photovoltaic (PV) systems in Malta, with potential lessons for the rest of Europe.
Over the past decade, government grants and community schemes have helped solar power spread rapidly across the island, which is home to about 580,000 residents: a number that swells each summer with tourists.
“Since around 2010, we’ve gone from almost zero solar power uptake to around 20-22%,” says Dr Azzopardi.
As solar power has expanded, however, a new challenge has emerged. Faults in PV systems often go unnoticed until electricity production has already fallen. By that point, the damage to the panels may already be significant.
To catch problems earlier, the researchers developed digital twins: digital replicas of real solar installations that allow different scenarios to be tested and potential faults to be identified before they affect the panels.
 
They also developed AI tools that scan incoming data around the clock, flagging faults automatically rather than waiting for somebody to notice a fall in performance.
The research also focused on developing the next generation of solar specialists. Malta’s rapidly growing solar sector still lacks enough technicians and researchers with the expertise needed to keep systems operating efficiently. 
By training people locally and sharing what they learn internationally, the team hopes Malta’s experience can benefit the rest of Europe.
To achieve this, the researchers combined high-tech monitoring across 10 Living Labs – real-world test sites – with new approaches to PV reliability, education and training, including international summer schools that attract students from around the world.
Solar uptake, warns Dr Azzopardi, is only half the story. “You see solar panels on rooftops, but whether they are working properly is still a question mark. Maintenance matters too.”
Most solar systems in Malta are small and privately owned, so their owners cannot rely on large maintenance contracts or sophisticated monitoring systems. Many assumed that once the panels were installed, little further attention would be needed.
“It’s true there are few moving parts, but maintenance is still needed. Bird droppings and environmental conditions such as shade from new buildings or damage to the panels can all affect performance,” he says.
The researchers installed commercially available sensors to measure electricity production, sunlight, wind and temperature.
The data fed into monitoring software capable of predicting when maintenance was likely to be needed, allowing repairs to be planned before faults caused significant losses in performance. Along the way, the team built valuable expertise that can now be applied in future research.
“Technically speaking, these systems are being tested in very harsh conditions in Malta,” says Dr Azzopardi. “If they survive here, they should survive anywhere in Europe.”
The Living Labs became even more valuable once their data started feeding directly into the training schools, giving students hands-on experience with real solar installations.
Participants visited the sites and worked alongside researchers using advanced diagnostic techniques such as electroluminescence testing, where electricity is fed back into a solar panel, causing the cells to emit faint infrared light invisible to the human eye. 
Specialised cameras then reveal tiny cracks and hidden defects that would otherwise remain undetected.
Students also developed practical inspection skills, learning how to assess panels visually and document faults using photographs and structured inspection checklists, a straightforward process that can still identify a surprising number of problems.
Teaching these diverse skills effectively, however, is no simple task, said Melodie de l’Epine, who leads research and innovation activities at the Becquerel Institute in France – a specialist PV research and consulting centre and a key member of the PROMISE team.
“Operations and maintenance for photovoltaics is a huge subject,” she says. To keep such a mixed group of trainees engaged, the team turned to games and role play.
 
“In the real world, operations and maintenance isn’t something you do in isolation. You’re receiving data, analysing problems, discussing budgets with management, and co-ordinating with maintenance teams – so I thought, let’s make them play the role,” says de l’Epine. 
The researchers developed three board games, matching exercises and simulation challenges, including a Monopoly-style game in which students take on the role of a technician troubleshooting a solar installation. Each activity focuses on different skills, from diagnosing faults to managing maintenance budgets.
For younger audiences, they also created Dance of the Photon, a live performance in which dancers demonstrate how sunlight is converted into electricity inside a solar cell, bringing an invisible process vividly to life.
The lessons could prove valuable far beyond Malta. Small-scale installations account for about half of Europe’s total PV capacity, and many face exactly the same maintenance challenges.
Developing smarter technology is only part of the challenge. Ensuring there are enough people with the skills to install, monitor and maintain solar systems will be just as important if Europe is to make the most of its growing investment in renewable energy.
“We need a strong, well-trained workforce that knows how to carry out maintenance and ensure longer system lifetimes,” says de l’Epine. “This requires a lot of training, but also for individual owners to acknowledge that maintenance is something they need to invest in.”
The research has shown that improving solar power is about much more than installing new panels. For Malta, one of Europe’s sunniest countries, harsh conditions have become an unexpected advantage. 
By testing technologies in some of Europe’s most demanding environments, the researchers are helping to develop solutions that could keep solar panels performing reliably across the continent for years to come. 
Author: Helen Massy-Beresford. This article first appeared in Horizon magazine.
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From pv magazine Germany.
The debate over the design of Austria’s subsidy framework has intensified since the last funding round, which saw its budget exhausted in just 33 seconds. Thousands of applications for photovoltaic and battery storage investment grants were left unfunded. Ahead of the third and final funding call opening in October, the Austrian government plans to present a redesign of the framework, which is expected to take effect next year.
On Thursday, the Ministry of Economy and Energy fleshed out its plans for a comprehensive storage offensive. Moving forward, the primary focus of new solar funding will shift toward storage. Storage infrastructure will be given greater weight in the new grid infrastructure plan, and the permitting process for battery storage is slated for acceleration. Additionally, the ministry is planning a dedicated funding program for intelligent energy management systems (EMS) for both residential and commercial applications.
Core points of the planned reform
The ministry also detailed its vision for investment funding under the Renewable Energy Expansion Act (EAG) from 2027 onwards. The highly competitive “first come, first served” model will be scrapped.
“Funding applications should in future be able to be submitted after installation and invoicing – based on the principle of the craftsman bonus,” the ministry stated.
Crucially for the storage sector, broad funding for small, standard photovoltaic systems will be phased out. Instead, financial support will pivot to energy management systems and smart storage to drive up self-consumption and relieve grid congestion. Under the new rules, retrofitting existing solar arrays with battery storage and EMS will also become eligible for subsidies.
Specialized solar applications—such as building-integrated photovoltaics (BIPV), agri-PV, solar carports, floating solar, and noise barrier installations—will remain eligible for support, alongside the preservation of the “Made in Europe” bonus.
“The challenge is not that we generate too little cheap domestic electricity in summer. We have to make it available when we need it. Used correctly, storage brings cheap solar power from midday into the more expensive evening hours,” explained Austria’s Minister of Economy, Wolfgang Hattmannsdorfer.
The government’s primary goal is to shift excess solar generation into the evening peak, thereby minimizing the need to import expensive power.
“For this we need more properly deployed storage – from households and large battery storage systems to our pumped hydro storage,” Hattmannsdorfer added.
8 GW of storage capacity needed by 2030
A dedicated storage study commissioned by the Ministry of Economy indicates that up to 8 GW of market-oriented storage capacity by 2030 would be economically beneficial for the country. Depending on the scenario, this additional battery storage could help drive down wholesale power prices by up to €2 per megawatt-hour in 2030.
Current forecasts show Austria has around 3.2 GWh of installed battery storage—mostly in systems under 50 kWh capacity—alongside 6.2 GW of pumped hydro storage.
Beyond restructuring subsidies, the Ministry of Economy highlighted a need for regulatory action from E-Control. Much like its German counterpart, the Federal Network Agency, the Austrian regulator is currently drafting a new framework for grid fees and establishing criteria for system-serving storage.
“At the same time, the number and design of the criteria for system-serving storage envisaged in E-Control’s current draft must be reviewed again. The framework conditions must be practical and sufficiently broad so that the storage ramp-up is not slowed down by requirements that are too narrow to be met,” the ministry stated.
Industry demands action over words
The Federal Association Photovoltaic & Battery Austria (PV&B Austria) has broadly welcomed the shift in focus. The association has been lobbying for a realignment of the subsidy system and is in active dialogue with the ministry.
“We welcome the fact that the federal government is now explicitly recognizing the importance of storage for the energy system. However, it is crucial that the announced storage offensive now also translates into concrete measures,” said Vera Immitzer, Managing Director of PV&B Austria. The industry group stressed that clarity on next year’s funding mechanisms must be established quickly, emphasizing that access must be uncomplicated and available early.
However, the sector remains somewhat skeptical. Hattmannsdorfer has repeatedly promised a storage offensive since taking office but has yet to deliver on implementation. A storage study commissioned last year by PV&B Austria already underscored the critical need for flexibility in the Austrian grid. A follow-up analysis confirmed that battery storage is already capable of effectively shifting solar generation away from midday peaks to high-priced evening windows.
“We are happy to continue to be available to the ministry as a sparring partner. Now it is a matter of words being followed by deeds. The industry is ready – it is crucial that the announced storage offensive is now actually implemented,” Immitzer said.
She noted that merely tweaking PV funding will not be enough to drive the necessary capacity additions.
“It must also continue to be possible to discuss tax relief. E-Control is also called upon to create appropriate, practical framework conditions for electricity storage. And grid operators must also integrate electricity storage more strongly into their grid development plans in the future,” Immitzer added.
Meanwhile, local solar installation firm Hansesun criticized the PV funding plans as “completely inadequate,” arguing for a simple tax break for systems via a climate investment allowance. Hansesun’s Marketing Manager Andreas Müller argued that without such measures, customers will continue to lack certainty over whether their investments will actually receive funding.
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In need of capacity, the PJM’s surplus interconnection process has produced limited results while MISO and SPP were studying roughly 15 GW and 14 GW each in the first half this year.
After an earlier reform effort proved ineffective, the PJM Interconnection is taking a second swing at creating a pathway for bringing generation online by using surplus interconnection capacity at existing power facilities.
Surplus interconnection service, called SIS, allows a new generator or energy storage system to connect to the grid at a power facility’s existing interconnection point, using that asset’s excess capacity interconnection rights.
Surplus interconnection reviews can be significantly faster than standard interconnection studies, and using existing interconnection capacity can avoid costly network upgrades, according to Gavin Ahern, a co-founder of Surplus Interconnection, an advisory firm.
PJM reformed its Surplus Interconnection Service rules in early 2025, but little has come from that effort.
Since 2023, PJM has received eight SIS applications and approved two of them, according to a late November presentation, the most recent information about the status of surplus interconnection requests by the grid operator.
PJM doesn’t release information about surplus interconnection service requests beyond periodic updates to its Interconnection Process Subcommittee, Jeffrey Shields, a PJM spokesman, said in an email.
In contrast, the Midcontinent Independent System Operator was studying 14.8 GW of surplus interconnection requests as of June 30, followed by the Southwest Power Pool at 14.3 GW, Western utilities at 6 GW and Southeastern utilities at 1 GW, according to an analysis by Surplus Interconnection. PacifiCorp was reviewing 33 projects in five Western states totaling 5.2 GW as of Aug. 13, according to its surplus queue. And in the last 60 days, it has filed five surplus interconnection agreements for approval by the Federal Energy Regulastory Commission.
The majority of the pending surplus interconnection requests are for battery storage projects.
Forty-four surplus interconnection projects have come online in MISO and 22 have started operating in SPP’s footprint, according to the report. Since 2024, it took one year for the project in MISO to come online, on average, and projects in SPP took almost two years, according to the report.
“MISO and SPP built surplus interconnection processes that actually work operationally, for example allowing for parallel operation of an existing and surplus generator at the same point of interconnection, which is critical for surplus projects to pencil out,” Ahern said in the report.
Thermal and renewable energy generating facilities in PJM have surplus interconnection capacity that could support about 150 GW of solar, wind and storage, although the loss of federal tax credits has reduced that potential, according to a working paper by University of California, Berkeley, researchers released in August 2025.
PJM is taking steps to make its SIS process more usable. The effort comes after PJM failed to meet its reserve margin targets in its last two capacity auctions, with the shortfalls growing to about 6.8 GW for the 2028/29 delivery from 6.5 GW for its 2027/28 delivery year, which begins on June 1.
“When PJM is looking around trying to answer the question, ‘How are we going to fill this deficit?’ resources coming online using surplus interconnection should be one of the first things that they grab for,” Grant Glazer, senior manager for regulatory and market affairs for MN8 Energy, a renewable energy and storage developer, said in an interview.
Surplus interconnection offers the fastest way to add new capacity to the grid by allowing the use of existing capacity interconnection rights, or CIRs, he said. Facilities that access the grid via SIS don’t require interconnection upgrades or new interconnection rights, making them less expensive, Glazer noted.
However, PJM’s current rules don’t allow a workable way for surplus additions to access the CIRs associated with an existing generator, according to Glazer.
Under PJM’s rules, a battery system added to a solar farm, for example, has two options to participate in the market: as a co-located resource or a hybrid resource, he said. But the co-located model doesn’t allow the battery access to the CIRs that may be needed to participate in PJM’s capacity market and the hybrid model doesn’t work because the entire resource can only have one market participation ID.
Having a single ID makes it impossible to untangle which resource in the hybrid facility is participating in the energy and ancillary services markets, so it is impossible to settle existing offtake agreements for the existing resource, Glazer said.
To address the issue, PJM staff earlier this month floated the idea of allowing hybrid resources — which participate in the capacity market as a single resource — to participate in the energy and ancillary services markets as separate and independent resources, according to an “issue charge” that is under review. Any rule changes would be developed by PJM’s Market Implementation Committee.
The plan will provide a “workable” pathway for many potential projects, according to Glazer.
Advanced Energy United, a clean energy trade group, supports PJM’s effort.
“We think these fixes are relatively easy, and given how desperately PJM needs new resources, we’re optimistic that this is going to move forward quickly,” Jon Gordon, AEU senior director, said in an interview.
Looking ahead, there are more complicated reforms that could be taken up later around CIRs that would further facilitate surplus interconnection, he said.
MN8 has been looking across its portfolio to find projects that have capacity interconnection rights that are being underused, according to Glazer. Many projects in PJM, especially solar projects, have CIRs that cover 40% to 60% of their nameplate capacity, leaving spare interconnection capacity, he said.
Battery costs have fallen and there’s a surge in demand in PJM for capacity resources, driven by large loads, according to Glazer.
Further spurring the potential use of surplus interconnection, Indiana and Virginia passed laws this year directing utilities in their states to study the potential for surplus interconnection on their systems.
In addition, utilities may turn to surplus interconnection as a pathway for adding capacity at their power plants, whether it’s a solar farm or a thermal generator, according to Ahern.
“There’s definitely receptiveness to it because they’re getting requests from large loads to plug in, and/or they’re short capacity for their own systems needs already,” he said in an interview.
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FERC’s response to the proposals will likely “influence utility capital investment, data center development timelines and the allocation of reliability risks and costs,” ClearView Energy Partners said.
Utility associations supported the 2024 efficiency requirements for distribution transformers and oppose their repeal. The rule may threaten national security, DOE says.
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FERC’s response to the proposals will likely “influence utility capital investment, data center development timelines and the allocation of reliability risks and costs,” ClearView Energy Partners said.
Utility associations supported the 2024 efficiency requirements for distribution transformers and oppose their repeal. The rule may threaten national security, DOE says.
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The global solar PV manufacturing landscape is evolving rapidly, with technology roadmaps diverging across regions. While China advances beyond first-generation TOPCon into back-contact (BC) and hybrid architectures, hubs like India, Europe, and North America are balancing TOPCon expansion, HJT, and tandem concepts.
To help you navigate these shifts, TaiyangNews is hosting the Cell & Module Production Equipment & Processing Materials Conference, bringing together top equipment manufacturers, material suppliers, and PV makers.
At the conference, Archon Lai, Chief Marketing Officer at China S.C, will be speaking on the topic: Innovation for Next-Generation Solar Cell Manufacturing.
The virtual conference is scheduled from 09:30 to 13:00 CEST on Tuesday, August 25, 2026. Register for free here.
BOE Energy’s 200 MW Pasture-PV-Storage + Sand Control Comprehensive Project in Inner Mongolia’s Xilingol League has been selected as a representative case in the ‘New Energy/PV Desertification Control’ category of the report Desertification Control and Land Restoration – Inspiring Solutions from Chinese Enterprises. The report was released on August 18, 2026, at a China Pavilion side event during the 17^th Conference of the Parties to the United Nations Convention to Combat Desertification (UNCCD COP17).
The project adopts a ‘PV + energy storage + desertification control + livestock farming’ model. Elevated mounting structures allow PV generation above and grazing below, while shading and wind protection from the modules help improve the surface microenvironment.
BOE Energy is the energy development subsidiary of display manufacturing giant BOE.
Chinese energy developer Energy China (CEEC) has announced the results of its 2026 centralized procurement of lithium iron phosphate (LFP) energy storage systems (ESS) and battery cells, with a total procurement volume of approximately 30 GWh. The procurement covers four lots: 1C (1-hour), 0.5C (2-hour), and 0.25C (4-hour) ESS, as well as LFP battery cells.
A total of 36 companies won bids, including CATL, Sungrow, JA, and Risen Energy. However, as the announcement did not disclose the specific capacity of each lot, the winning unit prices for individual suppliers cannot be calculated.
Recently, CEEC released the preferred bidders for its 2026 centralized PV inverter procurement, with an estimated total capacity of 20 GW (see China Solar PV News Snippets).
PV and energy storage manufacturer Trinasolar, together with research teams from Fudan University and Southeast University, has published research in Nature on perovskite/perovskite/crystalline-silicon triple-junction solar cells. The study addresses non-radiative losses in wide-bandgap perovskites and suboptimal light management across the multilayer stack.
The researchers combined defect passivation of wide-bandgap perovskites with optical management to address key electrical and optical limitations in triple-junction devices. The devices achieved certified steady-state efficiencies of 32.22% for a 1.046 cm² aperture area and 26.97% for a 15.62 cm² aperture area. Trinasolar said both efficiencies are records for triple-junction cells, and the research provides a technical pathway for lightweight, high-efficiency, and stable multijunction tandem PV devices, including for space applications.
China National Nuclear Corporation (CNNC) has announced the preferred bidders for its 2026-2027 centralized procurement of solar PV modules, with the tender expected to cover about 4.3 GW. The procurement includes both TOPCon and back-contact (BC) technologies, allowing bidders to select a route based on their available production capacity.
Six companies were named as preferred bidders, with quoted prices of RMB 0.71/W for Astronergy, RMB 0.695/W for JA, RMB 0.69/W for Yingli Solar, RMB 0.70/W for Tongwei, RMB 0.748/W for Huayao PV, and RMB 0.685/W for LONGi.
Leading PV encapsulant film manufacturer Hangzhou First reported operating revenue of RMB 6.988 billion for the first half of 2026, down 12.2% year-on-year, while adjusted net profit rose 62.57% to RMB 729.6 million. The company attributed the increase mainly to higher profits from its PV products, photosensitive dry film, and aluminum laminated film businesses.
Note that the reported adjusted net profit is lower than Hangzhou First’s forecast in July (see China Solar PV News Snippets).
PV encapsulant film sales volume fell 11.97% year-on-year to 1.2202 billion m² during the period. Hangzhou First said its encapsulant film business profitability recovered significantly as capacity held by loss-making producers continued to exit the market and smaller encapsulant manufacturers gradually withdrew, easing competition in the industry. Sales volumes of photosensitive dry film and aluminum laminated film increased 21.92% and 29.38%, respectively, to 109 million m² and 8.6145 million m².
TaiyangNews 2024

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Swedish renewables developer OX2 has officially begun construction on the Muswellbrook 100 MW / 200 MWh battery energy storage system (BESS) in the Hunter Valley, some 250 kilometres north-west of Sydney.
The site is a hybrid and includes a 135 MW solar farm that will connect to the Hunter-Central Coast Renewable Energy Zone (REZ). 
Located at the site of a former coal mine that shut down in 2022, the project located near the coal mining town of Muswellbrook and called the Muswellbrook BESS, will supply enough electricity to power about 52,000 homes, helping strengthen grid reliability for the Hunter-Central Coast REZ.
The project is being delivered by OX2 and co-developed with Idemitsu Australia, the owner of the former coal mine and the site’s retaining owner. It reached financial close in May 2026 and is expected to support around 200 construction jobs.
“Today’s sod turning marks the beginning of construction on a project that demonstrates how Australia’s energy transformation can deliver lasting benefits for regional communities,” said OX2 Australia vice president Stephen Symons. 
“By repurposing a former coal mine site into a renewables hub, we’re investing in infrastructure that will provide reliable energy, create local jobs, strengthen regional supply chains and support the Hunter’s future prosperity.”
Construction costs are estimated to be $302 million for the Muswellbrook solar farm and BESS. It is one of nine developments signed under long-term Amazon Australia power purchase agreements (PPAs), as part of the tech giant’s 430 MW, $2.8 billion renewable energy buy-up. 
Through a Community Benefit Sharing Program agreed with Muswellbrook Shire Council, OX2 will contribute $115,000 each year to support local projects. 
EnergyCo has commissioned Ausgrid to upgrade REZ‑designated distribution infrastructure to unlock 1 GW of network capacity by 2028, enabling OX2 to connect as soon as construction is complete. 
“It’s pleasing to see that the additional network capacity we are building in the Hunter-Central Coast REZ is already unlocking new renewable energy and storage projects, delivering economic benefits to the Hunter region,” said EnergyCo chief executive Hannah McCaughey. 
The Muswellbrook BESS is expected to be operational in 2028.
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The site could offer cheaper power, safer outdoor space, and new opportunities for work, training, and green manufacturing.
Photo Credit: iStock
Local advocates say the former New York Post printing complex on the South Bronx waterfront could serve a very different purpose in the future.
Instead of remaining vacant, its roof could host a community-owned solar project designed to lower electricity costs, create jobs, and expand access to cleaner energy in a neighborhood long affected by pollution, the Bronx Times reported.
One idea newly introduced by South Bronx Unite centers on the roof of the more than 350,000-square-foot property. Rooftop solar would anchor a broader redevelopment effort shaped by the community.
South Bronx Unite presented the concept at one of its regular community meetings, where MIT research fellows also took part.
The gathering also marked the launch of the group’s Energy Justice campaign, and organizers connected the proposal to familiar neighborhood concerns such as high electric bills and health effects tied to nearby fossil fuel infrastructure.
News Corp started operating at the plant in 2001, then moved its printing work to College Point in 2021. Advocates say the waterfront site has been mostly unused since then, creating an opening to consider uses that benefit residents instead of bringing more truck traffic and pollution.
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The proposal was also discussed at the meeting by Dr. Diana Hernandez, an associate professor of Sociomedical Sciences at Columbia University’s Mailman School of Public Health.
“Places like the Bronx are very much impacted by issues like energy insecurity. And yet, there are solutions,” Hernandez said.
The site is controlled by the Galesi Group through a 99-year lease from Empire State Development Corporation, and part of the property was leased to FreshDirect in 2011.
South Bronx Unite says FreshDirect got $127.8 million in state tax breaks to keep the company from leaving New York. The organization, which has long pushed back against projects it says worsen local air quality, wants planning to start before another truck-heavy operation moves in.
Organizers say the question is about more than just land use. In a neighborhood that has faced environmental burdens for years, cleaner energy could help lower utility costs while also reducing reliance on polluting power sources.
Residents also suggested ideas such as green space, urban farming, flood protections, walking trails, and better transit access.
The site could offer cheaper power, safer outdoor space, and new opportunities for work, training, and green manufacturing.
South Bronx Unite has begun a pre-feasibility solar assessment with Working Power. That group helped secure Sunset Park Solar, the city’s first community-owned solar project, and organizers are also seeking pro bono legal help because of the property’s complicated ownership and lease structure.
Numbers shared at the meeting indicate the roof could generate about $3.1 million in operating income over 25 years. Under the proposal, around 100 households could get a 20% reduction on electricity bills, saving an average of $142 per year.
Organizers said the system could produce roughly twice the energy of the Sunset Park Solar Project.
They also said that because the project would be community co-owned, money beyond those direct savings could be directed back into the neighborhood through a community-governed process.
South Bronx Unite has not set a firm timeline, but estimates the full vision could take up to seven years. The group plans to start a working group later this month and continue it through at least mid-2027.
“There is a nationwide struggle for the liberation of these lands,” said community organizer Kaila Paulino. “We don’t have an answer, but that’s why we want to have this conversation.”
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From ESS News
China-based storage system manufacturer Ecoflow has been teasing an update to its Stream series of products and has now launched the products in the UK, following an earlier launch in Europe, with the Stream 5000 and Stream AC 5000 now available for pre-order.
Previous Stream models such as the Stream Ultra remain on sale, but the expanded portfolio in the UK now includes 5 kWh batteries with both the Stream 5000 and Stream AC 5000, along with a 5 kWh expansion battery option as well. When paired with solar generation or expansion batteries, the Stream 5000 can deliver up to 3 kW of output power according to EcoFlow.
The EcoFlow Stream 5000 has a maximum charging power of 4 kW, maximum discharging power of 3 kW. The main unit battery for this modular system has charging and discharging power of 2.5 kW. EcoFlow Stream 5000 is rated for a 3 kW AC charging input. EcoFlow Stream 5000 are equipped with four maximum power point trackers (MPPT) and take a PV input power of 5 kW (across four 1.25 kW inputs) at a maximum PV input voltage of 60 V.
For AC output, this varies between off-grid and grid tied, with off grid rated at 3 kW and grid-tied AC output listed as 800 W/3 kW on the product specification sheet. The Stream 5000 has a net weight of 45.4 kg, dimensions 295 mm x 489 mm x 298 mm, and carries a 10-year warranty.
EcoFlow Stream AC 5000 has nearly identical specifications but the main difference is that it doesn’t offer an inverter for charging from solar PV. It has a maximum charging power of 3 kW rather than 4 kW, and a slightly lower weight at 44.6 kg.
The EcoFlow Stream 5000 and EcoFlow Stream AC 5000 each offer a lifespan of 10,000 cycles.
All products in the EcoFlow 5000 range are equipped with low-temperature charging activation at below 10 C, have an IP65 ingress protection rating and a maximum 30 dB noise specification, according to the manufacturer.
Other novel features
EcoFlow highlighted that the new Stream 5000 series offers is able to work with its last generation of Stream products to host an expanded capacity of up to 90 kWh.
It also offers a “local” mode, for operation without cloud control. The company also noted two pressure relief valves in the latest models; the safety mechanisms designed to manage off-gassing that occurs during thermal runaway.
Pricing and availability of the EcoFlow Stream 5000 and Stream 5000 AC UK
Introductory or early-bird pricing for the EcoFlow Stream 5000 is £1599, while the Stream AC 5000 is £1499. Early bird pricing is available until October 7.
On the EcoFlow UK website, an offer describes paying £9.90 to lock in a launch offer to save £100.
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April 01 – August 31, 2026
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SunShare, a US-based community solar developer, has completed and energized its first two New Mexico community solar gardens with CSolPower. The 6 MW DC Juniper Sol garden in Santa Fe reached commercial operation recently and started producing renewable energy. Juniper Sol agri-pv occupies 31 acres and its generation capacity is equivalent to powering nearly 2,000 homes while avoiding 261 million pounds of CO2. The pv-garden will incorporate agrivoltaic practices, including native, pollinator-friendly habitats under and around the solar panels. Half of Juniper Sol subscribers are income-qualified, while 2,000 families will save on electricity costs for the next 25 years. Rockhound Sol, a 4.5 MW DC solar farm in Deming, was energized alongside Juniper Sol project. Alongside the Juniper Sol installation, SunShare has committed more than $7 million in donations to three community organizations in New Mexico.
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Indian solar manufacturer Websol Energy System has started upgrading one of its existing monocrystalline PERC cell lines to TOPCon technology, with the project expected to be completed by March 2027.
The company is converting a 600 MW mono PERC line into a 750 MW TOPCon line at its existing facility. The upgrade will increase Websol’s total cell manufacturing capacity from 1.2 GW to approximately 1.35 GW. Once completed, TOPCon will account for around 55% of the company’s cell capacity.
The upgraded line is expected to achieve a cell efficiency of around 25%.
Websol is also targeting further reductions in silver consumption as it transitions to TOPCon technology. TOPCon cells, which currently dominate global crystalline silicon production, consume more silver than earlier technologies such as PERC, making them particularly sensitive to price volatility.
The company said it reduced silver consumption by 20% in the 2025-26 financial year and is targeting a further 10% reduction. Over the longer term, Websol is evaluating alternative metallization pathways to reduce its reliance on silver.
The company is also planning a 4 GW integrated cell and module manufacturing facility, to be developed in phases to mitigate the risk of technology changes as the solar industry evolves.
The company plans to locate the expansion close to its existing operations in West Bengal, to benefit from easy access to an established supply base and skilled workforce and potentially shorten the time required to bring new capacity online.
“Recent direction of the state [West Bengal] towards greater industrialization, including the proposed new industrial policy, simpler access to industrial land and a stronger focus on attracting manufacturing investment is encouraging for companies like ours, which already have an operating base here.  So, we look at West Bengal not merely as the location of our existing plant but as a natural place to consider for the capacity we build next,” stated the company.
Websol has partnered with Linton Crystal Technologies for equipment and technology support for its planned greenfield ingot and wafer manufacturing facility.

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Plug-in solar panels to hit supermarket shelves – will they save you money?  Yahoo
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In Sydney, 14,000 native plants gave rooftop solar a 23% performance boost  Yahoo
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ATOME is preparing a feasibility study for a proposed 300 MW solar project in Villeta
Progress on the project depends on ATOME Paraguay moving forward with a PPA
It says the project could support the development of an industrial park centered on solar power and battery storage
ATOME PLC, a UK-listed developer of green fertilizer and renewable energy projects, says it has secured financial and technical support to study a proposed 300 MW solar PV project in Paraguay.
The support, secured from a multilateral development bank’s dollar fund, will be used to develop a feasibility study for the project, planned near ATOME’s green fertilizer plant in Villeta. The company said it has access to substantial land in the area for solar development.
The feasibility study will proceed if ATOME Paraguay moves forward with the relevant Power Purchase Agreement (PPA). ATOME said the project could support the development of an industrial park centered on solar power and battery storage.
It expects the proposed facility to support new industries and trades linked to its green fertilizer operations.
Paraguay’s renewable electricity supply is supported by the 14 GW Itaipu hydroelectric dam, which is co-owned by Paraguay and Brazil. The company said the broader Mercosur region (Argentina, Brazil, Paraguay, and Uruguay) has limited domestic fertilizer production and imports about 30 million tons of fertilizer annually, equivalent to about 95% of its demand. Hence, it sees Paraguay as the prime location for a decentralized production facility to supply the larger region.
Paraguay also has renewable energy ambitions, targeting a 60% share of renewable energy in its total energy consumption by 2030. However, solar PV accounted for only 3 MW of the total 8.85 GW installed renewable energy capacity at the end of 2025, according to the International Renewable Energy Agency.  
TaiyangNews 2024

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The solar photovoltaic system at the Duff House Pump Station in Manchester is expected to result in over $14 million in savings on electricity costs.
Agriculture Minister Floyd Green noted that the investment will also support farmers, especially amid drought conditions, ensuring food security.
He was speaking at the official commissioning ceremony for the system on Thursday.
The system, implemented by the National Irrigation Commission Limited, will supply water to farmers through climate-smart, reliable irrigation infrastructure.
Mr. Green said about 450 farmers will benefit.
 
 
The Minister noted that systems operated by the NIC consume a lot of energy.
The solar system will reduce the NIC’s dependence on power from the Jamaica Public Service.
 
 
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Education Minister Dr. Dana Morris Dixon has announced plans to amend the HEART/NSTA Trust legislation…
While the Bank of Jamaica’s (BOJ) priority remains focused on low and stable inflation, there…
IRIE FM began test transmissions in July 1990 with a heavy bass line and rocking Reggae rhythms. The station officially went on air on August 1, 1990. Reggae in the morning, Reggae in the evening, Reggae in the night was the cry. Critics said it was impossible to sustain a 24-hour Reggae music station. In fact, so strong was the impact, it proved that this format was something the Jamaican public yearned for. The little station that could got all media houses in Jamaica to stand up and take note. The nay-sayers did not count on the strength of 40 years worth of rich, pulsating Jamaican music.
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Queensland biofuel groups seek national ethanol and biodiesel mandate
US renewable fuel credit generation rises nearly 7% in first seven months of 2026
Bangchak expands used cooking oil network to support SAF production in Thailand
Egypt approves 1-GW solar project with 600-MWh battery storage
US renewable fuel credit generation rises nearly 7% in first seven months of 2026
US fuel ethanol production falls nearly 3% in week ended August 14
Guatemala’s E10 rollout opens new market for US ethanol
Ethanol blending can support farmers, industry and economy: West Bengal minister
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BPCL builds district-level compressed biogas ecosystem in Madhya Pradesh’s Satna
Finland opens first large-scale liquefied biogas plant
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Inventure, CPM|Crown partner on catalyst-free biodiesel technology
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The Egyptian government has granted a golden licence to Nefer Minya Renewable Energy to develop a 1-GW solar power plant with a 600-MWh battery energy storage system in Minya Governorate.
The project is being developed by a joint venture between Infinity Power Holding and HAU Energy and is expected to require an investment of about $750 million, according to a statement from the Egyptian Cabinet, Renewables Now reported.
The developer is seeking $170 million in financing from the European Bank for Reconstruction and Development (EBRD), with a decision expected by September 9.
The project is expected to employ about 2,500 engineers, technicians and workers during construction. It is also expected to generate additional employment once the plant becomes operational.
The solar and battery project will be built on a 20-square-kilometre site west of the Nile in the West Minya area. Construction is scheduled to be completed by September 30, 2027.
Egypt’s golden licence is intended to speed up major investment projects by bringing key approvals, including construction permits and land allocation, under a single authorisation.
The government has been granting the licence to a growing number of projects as it seeks to accelerate renewable energy development and increase the share of renewables in the country’s power mix to 45% by 2028.
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