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For anyone who has followed SNEC for more than a few years, the basic rhythm of the show is familiar: bigger booths, louder launches, higher module wattages and increasingly confident claims about the next phase of solar. SNEC 2026 felt slightly different.
The solar segment was still vast. Major Chinese manufacturers showcased new modules, efficiency gains, cell roadmaps and carefully staged glass displays. TOPCon remained ubiquitous, and high-power modules continued to dominate headlines and booth graphics. Yet the underlying message was no longer simply that modules are getting more powerful. That narrative is now largely established.
Instead, PV was increasingly framed as part of a broader system conversation: storage, dispatchability, AI, grid stability, differentiated applications and, at the margins, even space-based use cases. In short, SNEC 2026 reflected an industry still focused on efficiency gains, but increasingly aware that efficiency alone will not define the next cycle.
Here are five trends that stood out.
Storage has shifted from the periphery of PV discussions to a core design element. This does not diminish solar’s role; it redefines it.
For years, the industry’s central promise was simple: cheaper electricity. That promise has largely been delivered on the generation side. The challenge now is less about cost and more about value — how electricity is absorbed, shifted, dispatched and integrated into constrained grids.
This was evident across SNEC, where many PV players no longer positioned themselves as module suppliers alone.
Longi highlighted this shift with its Longi ONE platform, positioning it as an integrated solar-plus-storage system spanning utility-scale, C&I, microgrids, power conversion systems and intelligent dispatch. Founder and CTO Li Zhenguo described the move into storage not as diversification, but as an “extension of capability” — framing storage as the next layer of value beyond high-efficiency PV.
JinkoSolar took a similar approach, pairing its Tiger Neo 5.0 module with scenario-specific PV products and the SunTera G5 storage system. The message was clear: module supply alone is no longer sufficient for customer needs.
Across markets, buyers are increasingly asking for more than low module prices. They want higher self-consumption, reduced curtailment, grid compliance, output smoothing and improved long-term project returns. That shifts procurement logic: modules remain essential, but system value is becoming decisive.
Back-contact (BC) technology was one of the most visible themes at SNEC. It is still not a mass-market replacement for TOPCon, which remains the dominant volume platform, but BC is clearly moving beyond niche status.
Companies including Longi, Aiko, TCL Zhonghuan, Skyworth PV and SolarSpace all used SNEC to expand BC-related product narratives.
BC removes front-side metallization, reducing shading and improving aesthetics — a key factor in residential and C&I rooftop markets. But positioning at SNEC went beyond appearance, emphasizing higher current density, improved shading response and greater design flexibility.
Aiko’s G4 INFINITE Ultra module was among the most prominent examples, with reported peak efficiency of up to 26% and a 690 W format. Skyworth PV showcased an 825 W BC module, while TCL Zhonghuan presented a BC platform exceeding 710 W and 26% efficiency.
Longi framed BC more broadly as a scalable platform technology, compatible with multiple cell architectures and differentiated module designs, including anti-dust, lightweight and anti-glare variants.
The key takeaway is not a near-term replacement of TOPCon, but the emergence of BC as a premium platform for distributed and high-value applications, while TOPCon remains the industry’s volume backbone.
AI was omnipresent at SNEC, though not all claims carried equal technical weight. Still, beneath the marketing layer, a clear direction is emerging: AI is becoming a functional layer across design, manufacturing, operations and energy management.
Huawei Digital Power offered one of the clearest articulations of this shift. At its SNEC launch, the company emphasized grid-forming technologies and AI as “pervasive” system elements. It also introduced FusionSolar Agent, an AI-driven system designed for lifecycle management of renewable assets.
The relevance for PV lies in increasing system complexity. A solar plant is no longer just modules and inverters, but a multi-variable system involving forecasting, dispatch, grid compliance, maintenance and increasingly energy trading — especially as storage penetration rises.
AI applications also extended into manufacturing and O&M, including defect detection, yield forecasting, predictive maintenance and carbon asset management tools.
The next phase will depend less on AI positioning and more on measurable outcomes: higher availability, improved yield prediction, lower O&M costs and better dispatch accuracy. Differentiation will come from integration depth, not branding frequency.
The one-size-fits-all module concept is steadily fading. SNEC 2026 featured a wide range of application-specific designs targeting data centers, desert environments, offshore installations, transport corridors, C&I rooftops and low-load structures.
JinkoSolar illustrated this shift with a diversified product matrix, including anti-glare, dust-resistant, lightweight and high-safety modules, alongside its AIDC and desert-focused designs.
Industry observers such as EnergyTrend noted a broader shift: module differentiation is no longer only about peak wattage, but about application fit and lifecycle performance.
Tongwei’s TNC 3.0 platform reflected similar priorities, with emphasis on temperature coefficients, bifaciality, low-light performance and degradation control. CTO Xing Guoqiang also pointed to weaker demand conditions ahead, driven by policy changes in China, trade restrictions and grid constraints in overseas markets — reinforcing the need for higher system value per project.
The industry narrative is shifting from “more watts” to “better fit and lower risk,” with increasing focus on LCOE optimization under specific operating conditions.
One of the more unexpected themes at SNEC was the visibility of space and aerospace PV concepts. This remains far from a commercial mainstream segment, but its presence signals the industry’s search for higher-value frontiers.
Risen Energy presented Risen Flex Nova, a lightweight, ultra-thin heterojunction-based concept targeting satellite and low-Earth orbit applications. Reported features included ultra-thin wafers, flexible structures and radiation resistance.
While volumes will remain limited, the technology direction overlaps with terrestrial trends: thinner wafers, material reduction, lightweight modules and high-efficiency architectures such as HJT and tandem concepts.
Space PV is best understood as a long-horizon exploration rather than a near-term market. Its significance at SNEC is less commercial and more symbolic: it reflects how far PV companies are pushing the boundaries of application environments.
SNEC 2026 did not suggest that the industry’s structural challenges are easing. Overcapacity, pricing pressure, trade barriers and grid constraints remain firmly in place. If anything, they were more visible, as companies sought to justify value beyond cost reductions.
But the direction of travel was clear.
Solar is still a manufacturing industry, but it is increasingly becoming a systems industry: integrated with storage, enabled by software, shaped by applications and constrained by grid realities. Future competition will still depend on efficiency and cost, but also on dispatchability, system integration, service capability and lifecycle performance.
That shift makes the industry more complex to describe — and more interesting to follow.
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SHANGHAI, June 12, 2026 (GLOBE NEWSWIRE) — Highjoule's self-developed foldable solar container and supporting energy storage system are currently undergoing orderly production and preparation for shipment to the United States, marking the company's innovative mobile solar-storage integrated solution's successful entry into the North American high-end market for the first time.

The system features a 5kWp framed foldable photovoltaic (PV) system as its power generation core. Designed specifically for the diverse terrain and windy conditions commonly found across the United States, the solution incorporates an innovative ground-anchor fixation system and has undergone rigorous wind-resistance testing to ensure operational stability under extreme weather conditions.
Built around the key advantages of rapid deployment and superior wind resistance, the system combines a modular folding structure with integrated solar generation and energy storage capabilities. It is well suited for emergency power supply, remote operations, temporary project sites, and distributed energy applications, providing U.S. users with a safe, efficient, and portable clean energy solution.
The successful completion of this order follows several months of comprehensive global supplier evaluations and stringent due diligence conducted by the U.S. customer. Ultimately, highjoule was selected for its strong in-house research and development capabilities, advanced manufacturing expertise in new energy equipment, proven project execution experience, and outstanding value proposition.

Following multiple rounds of technical assessments and on-site factory inspections, the customer concluded that highjoule possesses end-to-end in-house capabilities spanning structural design, electrical system integration, and final assembly testing. This vertically integrated manufacturing model enables greater quality control, competitive lead times, and cost efficiency, aligning closely with the customer's supplier requirements.
In terms of export compliance, both the foldable solar container and the accompanying energy storage cabinet have successfully passed relevant market access and certification requirements for the United States. The complete system complies with North American standards covering product safety, electromagnetic compatibility (EMC), and international transportation requirements, providing customers with confidence throughout the deployment process.
Four Core Advantages of the highjoule Foldable Solar Container Series
Rapid Deployment
Once delivered to the project site, the system can be unfolded and begin generating power within just a few hours. No extensive civil construction or permanent power station infrastructure is required, enabling immediate operation upon deployment.
Significant Reduction in Installation Costs
The system adopts a fully pre-assembled and pre-configured design, minimizing the need for specialized installation teams or heavy lifting equipment. This plug-and-play approach substantially reduces installation time, labor requirements, and overall project costs.
Modular Scalability
The solution supports parallel operation of multiple units and flexible capacity expansion. Customers can freely configure photovoltaic generation capacity and energy storage capacity based on project requirements, enabling scalable deployments ranging from tens of kilowatts to multi-megawatt systems.
Adaptability to Harsh Environments
Both the container structure and folding mechanism are specially engineered with enhanced weather-resistant protection. The system can operate reliably for extended periods in high-temperature, high-humidity, salt-spray, dusty, and other challenging environments, making it particularly suitable for off-grid locations and regions with weak or unstable grid infrastructure.
“This foldable solar-storage system destined for the United States embodies our vision of making green energy more accessible,” said Mr. Xu, Project Manager at highjoule. “By integrating power generation, energy storage, and power distribution into a standard shipping container, the system offers exceptional mobility, ease of deployment, and environmental adaptability. It is particularly well suited to the North American market's growing demand for mobile emergency power and temporary construction-site electricity. Our customers value not only our certifications and technologies, but also highjoule's ability to deliver comprehensive, one-stop solutions from system design to final product delivery.”
As global demand for flexible, reliable, and sustainable power solutions continues to grow, highjoule remains committed to innovation through independent research and development. Supported by advanced manufacturing capabilities and extensive international project experience, the company will continue to advance integrated solar-storage technologies and provide customers worldwide with high-performance, cost-effective clean energy solutions, contributing to a more sustainable and carbon-neutral future.

Contact Information:
HighJoule (HJ Group)
Hui Jue
[email protected]
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https://www.highjoule.com/
Disclaimer: This content is provided by HighJoule (HJ Group). The statements, views, and opinions expressed in this content are solely those of the content provider and do not necessarily reflect the views of this media platform or its publisher. We do not endorse, verify, or guarantee the accuracy, completeness, or reliability of any information presented. This content is for informational purposes only and should not be considered financial, investment, or business advice. Neither the media platform nor the publisher shall be held responsible for any inaccuracies, misrepresentations, or financial losses resulting from the use or reliance on the information in this press release. Globenewswire does not endorse any content on this page.
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Winnebago County Board rejects solar farm near Curran’s Orchard  MyStateline
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Saatvik Green Energy Limited, one of India’s leading solar PV module manufacturers, has been ranked among the Top 25 Global Solar PV Module Manufacturers in the latest 2026 assessment released by Wood Mackenzie, one of the world’s leading energy research and analytics firms.
The company has also secured its position within the top 4 rank amongst Indian solar PV module manufacturers, placing it alongside some of the country’s largest solar manufacturing companies and reinforcing its growing position within India’s rapidly expanding renewable energy ecosystem.
The ranking evaluates manufacturers across multiple parameters, including manufacturing scale, technological capabilities, supply chain integration, financial strength, product quality, ESG performance, and market competitiveness.
The recognition comes at a time when Saatvik is accelerating its growth ambitions through capacity expansion, technology enhancement, and investments across the solar value chain. The company currently operates approximately 4.8 GW of solar PV module manufacturing capacity and is pursuing strategic investments aimed at strengthening its position in both domestic and international markets.
Commenting on the achievement, Mr. Prashant Mathur, Chief Executive Officer, Saatvik Green Energy Limited, said, “Being recognised among the Top 25 global solar PV module manufacturers and among the leading manufacturers in India is a significant milestone for Saatvik. The ranking reflects our continued focus on manufacturing excellence, quality, innovation, and building a resilient solar supply chain. As India strengthens its position as a global renewable energy manufacturing hub, we remain committed to supporting the country’s clean energy ambitions through world-class products and sustainable growth.”
India has emerged as one of the fastest-growing solar manufacturing markets globally, supported by strong policy initiatives, increasing domestic demand, and growing global interest in diversified supply chains. As the sector continues to evolve, manufacturers with robust manufacturing capabilities, quality-driven operations, and long-term investment strategies are expected to play a critical role in meeting both domestic and international demand.

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Drivetime
Gypsy
Friday, 12 June 2026 15:57
Wills Bros Group are taking home the Judges Silver Award for their work on the Timahoe North Solar Farm.
The builders behind a Midlands solar farm have scored success at the Irish Construction Excellence Awards.
Wills Bros Group scooped the Judges Silver Award for its work on the Timahoe North Solar Farm.
The site has been operational since its official launch last year and is currently generating 15 mega watts of its planned 108 mega watt capacity, with the potential to power approximately 25,000 homes.
Winners by region:
MIDLANDS
Timahoe North Solar Farm
Winner: Judges' Silver Award
Lead Contractor: Wills Bros
Media Angle: Renewable energy project recognised nationally.
GALWAY
Doughiska Skatepark Upgrade
Winner: Judges' Silver Award
Project Team: Galway City Council, Browne Brothers and Vulcano
Media Angle: Popular community facility recognised nationally after €400,000 redevelopment.
Benedictine Monastery at Kylemore Abbey
Winner: Judges' Silver Award
Lead Contractor: Carey Building Contractors
Media Angle: Major heritage and tourism project at one of Ireland's best-known visitor destinations.
Clai Mór Housing Development
Winner: Residential Social & Affordable Housing (€5m-€25m)
Lead Contractor: OCC Construction
Media Angle: Galway social housing project recognised as one of Ireland's best residential developments.
Crokers Hill Social Housing
Winner: Architectural Design Excellence (Over €20m)
Lead Architect: van Dijk Architects
Media Angle: National recognition for innovative social housing design.
CORK
Fíor Uisce, Mitchelstown
Winner: Judges' Silver Award
Project Team: Michael M Lyons Building Contractors and Cork County Council
Media Angle: Cork housing project receives national construction excellence recognition.
Ballycotton Pumping Station and Wastewater Treatment Plant
Winner: Civil Engineering (€10m-€20m)
Lead Contractor: Glanua
Media Angle: Critical water infrastructure project wins national award.
Glounthane-Midleton Twin Track
Winner: Innovation Award (Over €200m)
Project Team: BAM and Iarnród Éireann
Media Angle: Rail infrastructure project recognised for innovation.
Treasury Annex Building
Winner: Commercial Project Award
Lead Contractor: PJ Hegarty
Media Angle: Cork city commercial development wins national recognition.
LIMERICK / CLARE
Killaloe Bypass and Shannon Bridge Crossing
Winner: Civil Engineering (€20m-€50m)
Lead Contractor: John Sisk & Son
Media Angle: One of Ireland's most significant transport projects recognised nationally.
University Hospital Limerick Acute Hospital Block
Winner: Healthcare Project Award
Lead Contractor: John Sisk & Son
Media Angle: Major healthcare investment recognised for construction excellence.
Tom Johnson House, Limerick
Winner: Fitout and Refurbishment (Over €10m)
Lead Contractor: Duggan Brothers
Media Angle: Landmark city-centre redevelopment receives national award.
2-3 Mallow Street, Limerick
Winner: Fitout and Refurbishment (€1.5m-€5m)
Lead Contractor: C&N Higgins
Media Angle: Historic city-centre restoration recognised nationally. 
WEXFORD
Rosslare Europort Terminal 7
Winner: Civil Engineering (Over €50m)
Lead Contractor: John Paul Construction
Media Angle: One of Ireland's largest port infrastructure projects wins national award
DUBLIN
Project Connect, RCSI
Winner: Overall Project of the Year
Lead Contractor: Bennett Construction
Media Angle: Overall winner of the Irish Construction Excellence Awards 2026.
UCD Centre for Future Learning
Winner: Education Project (Over €20m)
Lead Contractor: Walls Construction
Media Angle: National recognition for major university investment.
Trinity Portal
Winner: Education Project (Up to €20m)
Lead Contractor: Flynn
Media Angle: Award-winning university development.
Barrow Street Public Realm Scheme
Winner: Public Realm Project
Project Team: Dublin City Council and Actavo
Media Angle: Urban regeneration project recognised nationally.
Magazine Fort, Phoenix Park
Winner: Heritage and Restoration Project
Lead Contractor: Kelbuild
Media Angle: Important historic structure restored and recognised nationally.
MEATH
Enfield Wastewater Treatment Plant Upgrade
Winner: Engineering Design Award
Lead Consultant: AM Consulting Engineers
Media Angle: Water infrastructure project recognised for engineering excellence.
Enfield Wastewater Treatment Plant Innovation Project
Winner: Innovation Award (€20m-€200m)
Lead Contractor: Coffey
Media Angle: National award for innovation in wastewater treatment
NORTHERN IRELAND
Pennyburn-Culmore Trunk Sewer Rehabilitation Scheme
Winner: Innovation Award (Up to €20m)
Project Team: GRAHAM and Blockbusters Environmental Services
Media Angle: Northern Ireland project wins national innovation award.
Ballyliffin Beach Houses
Winner: Judges' Silver Award
Lead Contractor: Newtownstewart McKinney
Media Angle: Residential coastal development receives national recognition.
Shane Murray is succeeding Councillor Declan Harvey in the role.
Independent rep John Leahy is taking up the role in Birr.
It comes from analysis by the Banking and Payments Federation Ireland. 
The developer is appealing a planning condition to An Coimisiún Pleanála.
Festivals claim they'll lose thousands as a result.
Independent rep Brian Stanley highlighted the case of a young Portlaoise woman in the Dail.
It's part of a €6m investment.
He is sharing his own experience to raise awareness.
Thousands queued this morning for a chance to get tickets.
It comes after a wash out week of rain and wind.
SIPTU say transparency is needed around the phased closure of Carlow College.
Women's Community Projects Mullingar is launching their plan from 2026 to 2030 today.
Interactive breathalysers called ‘Fline­Box’ machines will be in place.
Muintir na Tíre works to develop community safety solutions.
The trial will resume on Friday.
Event organisers wasnt to help businesses develop stronger relationships across the county.
He is being charged with cultivating cannabis.
Laois Leisure in Portlaoise is withdrawing is offer of complimentary access to students sitting exams.
Offaly's Cathal Nolan from Ireland's Weather Channel says the worst we can expect here is localised flooding.
The Offaly TD wants the county's work to be considered in new targets set by the Housing and Energy Ministers.
Never miss a moment from Midlands 103
Feel Good Radio
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Storms are tearing apart India’s rooftop solar panels while the steel frames holding them up stay perfectly intact  Energies Media
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Avaada to Commission India’s Largest Solar Cell Manufacturing Facility in Nagpur  SolarQuarter
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As the world’s biggest producer and consumer of PV modules, China is well placed to become a global leader in sustainable PV recycling and circular manufacturing, writes Huan Li, a Research Fellow at Curtin University.
Over the past two decades, China’s photovoltaic (PV) sector has undergone unprecedented expansion, ranking first worldwide in PV module production for 17 consecutive years and in installed capacity for nine consecutive years.
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In the first quarter of 2025, China’s combined installed capacity of solar PV (946GW) and wind power (536GW) surpassed thermal power capacity for the first time, marking a major milestone in the country’s energy transition and signalling what is likely to become a long-term structural trend. By the end of March 2026, China’s cumulative installed PV capacity had further increased to approximately 1.24TW.
Under carbon-neutral development scenarios, projections suggest that China’s cumulative PV capacity could exceed 2.8TW by 2035 and potentially approach 6TW by 2050.
This rapid deployment is expected to result in a parallel surge in end-of-life (EoL) PV modules. Crystalline silicon (c-Si) modules, which constitute 85-95% of the market, typically have a design lifetime of 25-30 years. However, real-world lifetimes may be shortened to15-20 years or less due to failures and early replacements.
Model-based predictions indicate that China will experience its first major wave of PV decommissioning around 2030. However, substantial quantities of PV waste are already being generated during manufacturing, from weather-related damage, and through replacement under renewal initiatives. Estimates suggest PV waste could reach approximately 1.5 million tonnes by 2030 and increase to nearly 20 million tonnes by 2050.
More comprehensive projections indicate cumulative decommissioned capacity could reach 675-752GW by the end of 2045, corresponding to 50-60 million tonnes of waste modules. 
Importantly, this waste stream represents a significant secondary resource. Typical PV modules contain aluminium (~16%), glass (~67%) and smaller but high-value fractions such as silver (~300g/t), copper and high-purity silicon (6N purity). In particular, the silver grade in solar cells, which accounts for more than 60% of the economic value of a PV module, is approximately 24,100 g/t, enormously higher than that found in virgin ores.
Therefore, the EoL surge presents both an environmental challenge and a strategic opportunity for resource recovery.
To date, China has proactively established a regulatory framework to manage PV waste (Table 1). The system is anchored in overarching legislation such as the Law on Environmental Protection and the Law on the Promotion of Circular Economy, forming a top-down governance structure.
A key milestone is the 2023 policy, ‘Guidance on Promoting the Recycling of Retired Wind Power and PV Equipment’, issued by the National Development and Reform Commission (NDRC), which represents China’s first dedicated national directive on PV recycling. The policy outlines phased targets:
A game changer was the ‘Solid Waste Classification and Code Catalogue’, issued by the Ministry of Ecology and Environment (MEE) in 2024, which for the first time defined PV waste as recyclable waste rather than hazardous waste. This provides recyclers and processors with a more flexible regulatory environment for handling PV waste. Subsequent policy updates in 2024, ‘Action Plan for Large-scale Equipment Upgrading in Key Energy Sectors’, jointly issued by NDRC and the National Energy Administration (NEA), further emphasise equipment renewal, recycling technologies and financial incentives.
China’s approach can be characterised as a hybrid governance model. It incorporates elements like the Extended Producer Responsibility (EPR) framework used in the EU, where producers bear responsibility for EoL products, while adapting to China’s utility-scale PV deployment structure. Large power generation enterprises are expected to take responsibility for decommissioned equipment, supported by strong central coordination.
In parallel, China has rapidly developed a standardisation system for PV recycling since 2020, covering recycling processes, technical requirements, environmental management and material recovery. To date, approximately 15 standards (excluding local government standards) have been issued by entities at different levels, including industry groups, professional associations and central government authorities with varying degrees of regulatory authority.
A recent standard, ‘Technical Specification for Pollution Control of Waste Photovoltaic Equipment Recycling and Treatment’ (HJ 1463-2026), issued by MEE, is the first ministerial-level standard regulating pollution control requirements for PV recycling. These standards aim to ensure consistency, scalability and environmental compliance across the industry. In addition, a number of new standards are currently under preparation, review, or approval.
The recycling of c-Si PV modules is technically challenging due to their laminated “sandwich” structure, in which materials such as glass, silicon cells and metals are encapsulated within ethylene-vinyl acetate (EVA) layers. Effective recycling therefore relies on efficient delamination, followed by material recovery.
Three main approaches are being developed: 
After delamination, physical processes such as vibration screening, electrostatic separation, eddy current separation, density separation and froth flotation (physicochemical) are used to recover materials. Electrostatic separation, for example, has demonstrated effectiveness in recovering silicon powders. It should be noted that no single separation process can achieve complete purification of all materials; consequently, subsequent metallurgical processes are essential to obtain high-purity materials and enhance overall recovery value.
Hydrometallurgy plays a critical role in high-value PV recycling, particularly for solar cells, which typically account for more than 60% of the economic value recovered from end-of-life PV modules and largely determine the overall economic feasibility of the recycling process. Hydrometallurgical process is widely applied for recovering valuable metals such as silver and copper through selective dissolution and separation processes. These include:
These methods enable selective metal recovery but must balance extraction efficiency, operating cost, reagent recyclability and environmental impact.
Among them, nitric acid leaching remains one of the most conventional and efficient methods for silver recovery. Nitric acid is also extensively used in the manufacturing of PV silver electrodes, where silver is dissolved and processed into conductive pastes. However, despite its high efficiency, nitric acid is highly corrosive, generates NOx gases and is difficult to regenerate and reuse sustainably. Several hydrometallurgical systems originally developed for precious metal extraction in the mining industry, such as iodine-iodide and thiosulfate leaching, have also demonstrated feasibility.
Recent research has increasingly focused on developing more sustainable alternatives: for example, the use of non-toxic amino acids, including glutamate and histidine, for silver recovery from PV waste. These systems offer significant advantages, including reduced toxicity, improved environmental compatibility, and enhanced reagent recyclability.
Current research trends focus on integrating physical, thermal and hydrometallurgical processes into hybrid systems to maximise recovery efficiency. High-value recovery of silicon (≥6N purity) and silver is critical for achieving economic viability and industrial scalability.
China’s PV recycling industry is currently at an early but rapidly evolving stage. Several trends are emerging, including the entry of both established PV manufacturers and specialised recycling companies, the development of pilot and demonstration-scale recycling plants and increasing policy-driven industrial activity. 
In 2017, Huanghe Hydropower Development initiated pioneering research on the industrialisation of PV module recycling and the localisation of major equipment. This effort resulted in the development of an indigenous “high-quality integrated recycling” process with proprietary IP. By December 2021, the company established China’s first pilot recycling line in Xining, Qinghai, with an annual capacity of 30MW. 
China Energy Conservation and Environmental Protection Solar Energy has established a modular and container-based PV module recycling system centred on physical separation technologies. The platform integrates intelligent recognition and positioning of module components with automated process regulation and operational optimisation, resulting in enhanced dismantling performance and improved material recovery quality.
The pilot facility, deployed in Jianli, Hubei Province, is regarded as China’s first containerised PV module recycling line, with an annual processing capacity of approximately 10,000 tonnes. 
Nantong Riyixin Environmental Technology has introduced a combined physical-chemical recycling process for retired PV modules, supported by dedicated processing equipment and integrated recovery technologies. The system can recover major module materials with high efficiency and resource utilisation performance. According to reported data, the company’s first commercial-scale line can process around 15,000 tonnes of PV waste per year, achieving overall recovery rates above 92%. 
In addition, a number of major enterprises and research organisations, such as Changzhou Ruisai Environmental Protection Technology, Yicheng Zhizao Technology, Changsha Institute of Mining and Metallurgy, Inner Mongolia Runmeng Energy and Jerie Environmental Technology have also been actively involved in developing PV recycling technologies and establishing pilot or demonstration-scale processing lines.  
Overall, mechanical recycling technologies in China have advanced from pilot-scale demonstrations toward near-commercial or commercial deployment (TRL 7-9). In contrast, chemical and hybrid recycling technologies are generally still under development or at intermediate demonstration stages (TRL 4-6). Supported by growing market demand and an increasingly supportive policy environment, China’s PV recycling industry is currently undergoing rapid expansion.
Various technological routes, including physical, chemical and integrated hybrid processes, are being explored simultaneously. The emergence of modular and high-efficiency recycling systems is expected to further promote the large-scale industrialisation of PV recycling in China.
Despite the rapid progress in PV recycling technologies and policy development in China, several critical challenges remain before a fully mature, economically sustainable recycling ecosystem can be established.
China is well positioned to lead global PV recycling development due to its unparalleled installation and retirement scales, integrated industrial ecosystem and strong policy support. The convergence of regulation, technology and market forces is expected to drive the sector towards large-scale industrialisation.
In the future, PV recycling in China is expected to move toward industrial scale, high-value and low-carbon recycling systems, integrating mechanical, thermal and chemical technologies. Distributed recycling networks combined with centralised high-value recovery facilities may become an important industrial model to reduce transportation costs and improve economic feasibility.
In the long term, the establishment of closed-loop recycling systems, where recovered materials are directly reintroduced into PV manufacturing, will be critical for achieving a circular PV economy. Supported by strong policy incentives, large market demand and continuous technological innovation, China is well placed to emerge as a global leader in sustainable PV recycling and circular manufacturing.
China’s experience in policy and regulatory frameworks, technological development and market pathways can provide valuable references for other regions, particularly for relatively densely populated regions such as the EU. However, local conditions, such as those in Australia, including labour costs, geographic dispersion, environmental regulations and market capacity, may constrain the depth of participation along the PV value chain.
For instance, similar to conventional e-waste management, Australia has been primarily focusing on collection, dismantling and pre-processing, while downstream high value chemical and metallurgical recovery remains limited due to unfavourable capex and opex conditions. Future R&D efforts should therefore be closely aligned with local market structures and industrial conditions.

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China's mandatory national standard "Energy Efficiency Limits and Grades for Crystalline Silicon Photovoltaic Modules and Inverters" is currently in the "under approval" stage, the final phase before official release, according to information from the National Standards Information Public Service Platform cited by The Beijing News.

Several institutions involved in drafting the standard indicated that it is expected to be formally issued in the near future.

Related News CLSA: China AIDC Construction Plan to Boost Energy Storage Battery Demand; Top Pick CATL (03750.HK)
Against the backdrop of the industry as a whole not yet returning to profitability and leading enterprises still facing earnings pressure, analysts believed this supply-side adjustment driven by standards upgrades is becoming an important force reshaping the competitive landscape of the photovoltaic sector.

AASTOCKS Financial News

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NISE Maps 102.18 GW Floating Solar Potential Across India  SolarQuarter
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India has an estimated 102.18 GWp of floating solar photovoltaic (PV) potential across its water bodies, according to a report released by Union Minister for New and Renewable Energy Pralhad Joshi. The assessment, prepared by the National Institute of Solar Energy (NISE), identified approximately 1,946 square kilometres of water surface area as suitable for floating solar installations.
Methodology
The study assessed reservoirs, lakes, and other inland water bodies using hydrological and topographical parameters. Water bodies smaller than 10 hectares were excluded from the assessment. The study assumed that up to 20% of a water body’s total surface area could be utilised for floating solar deployment.
According to NISE, around 0.019 km² of water surface area is required to install 1 MW of floating PV capacity at a tilt angle of 5 degrees. The estimate is based on solar modules with a capacity of 545 Wp and 21% efficiency.
State-wise potential
Maharashtra recorded the highest floating solar potential at 16.28 GW, followed by Madhya Pradesh at 14.89 GW, Karnataka at 13.69 GW, Odisha at 12.81 GW, and Telangana at 10.72 GW. Gujarat was assessed at 6.32 GW.
The report also included a second data set based on different feasibility criteria. Under this assessment, Maharashtra’s potential was estimated at 40.70 GW, followed by Madhya Pradesh at 40.13 GW, Karnataka at 33.22 GW, Odisha at 31.00 GW, and Telangana at 17.53 GW.
Policy and total solar potential
With the inclusion of floating solar resources, India’s total assessed solar potential, combined with previously assessed ground-mounted solar resources, now stands at around 3,445 GWp.
The Ministry of New and Renewable Energy (MNRE) stated that it is working on a dedicated scheme to accelerate floating solar deployment across the country. MNRE Secretary Santosh Kumar Sarangi said the ministry is in discussions with the finance ministry regarding support for floating solar and agri-photovoltaics.
Related announcements
At the same event, MNRE launched an online portal for small hydropower (SHP) projects. Applications and disbursement will be processed through the portal, and projects will be required to adhere to a four-year completion timeline.
The Military Engineering Services (MES) signed a memorandum of understanding (MoU) with NISE for solarisation initiatives in the defence sector.
Sarangi also stated that the Border Security Force (BSF) has approached the ministry for support in solarising its border camps using solar power integrated with battery energy storage systems.
The featured photograph (Source: NTPC) is for representation only.
Power Grid Corporation of India Ltd (PGCIL) has sold its remaining 26% stake in four associate companies to Power Grid Infrastructure Investment Trust (PGInvIT) for Rs 5.07 billion.  The transfer, completed on December 30, 2024, aligns with share purchase agreements involving PGCIL, IDBI Trusteeship Services Ltd, PUTL (Powergrid Unchahar Transmission Ltd), and the concerned entities….
Read More PGCIL sells residual stake in four entities to PGInvIT
Adani Power Limited (APL) has completed the acquisition of Vidarbha Industries Power Limited (VIPL) for an estimated Rs 40 billion. The deal, finalised on July 7, 2025, gives APL ownership of the Butibori Thermal Power Project in Nagpur district, Maharashtra. VIPL was a wholly owned subsidiary of Reliance Power Limited (RPL). It had developed the…
Read More Adani Power acquires Reliance’s Butibori thermal project
The Uttar Pradesh New and Renewable Energy Development Agency (UPNEDA) has blacklisted a Prayagraj-based rooftop solar vendor empanelled under the PM Surya Ghar Muft Bijli Yojana, signalling tighter enforcement of the flagship solar scheme in the state. The agency barred the firm and forfeited its bank guarantee of Rs 2.5 lakh following complaints of non-compliance…
Read More UPNEDA blacklists rooftop solar vendor under PM Surya Ghar scheme
Avista has signed a nonbinding memorandum of understanding to take a 10% ownership stake in the North Plains Connector, a 3 GW high-voltage direct current (HVDC) transmission line by Grid United’s subsidiary.  This 420-mile line will connect the US eastern and western electric grids between Montana and North Dakota, enabling bi-directional power transport from various…
Read More Avista to acquire 10% stake in 3 GW North Plains Connector transmission project
Waaree Energies Limited has commissioned a 950 MW solar module manufacturing line at its plant in Degam, Chikli taluka, Navsari district, Gujarat. The facility began operations on 30 September 2025. In September 2025, the company also added four subsidiaries under Waaree Forever Energies Private Limited, including Waaree Forever Energies Three Private Limited incorporated on 24…
Read More Waaree Energies starts 950 MW solar module line in Gujarat
NHPC Limited has commenced construction activities for the 240 MW Uri-I Stage-II Hydro Electric (HE) Project in Uri, Baramulla district of the Union Territory of Jammu & Kashmir. Shri Bhupender Gupta, Chairman and Managing Director (CMD), NHPC, inaugurated the construction works on May 31, 2026, by initiating the first blast for Adit-3A to the Head…
Read More NHPC begins construction work for 240 MW Uri-I Stage-II project
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by FOX56 NEWSROOM
DAMASCUS TWP., WAYNE CO. (WOLF) — A controversial proposal to build a large-scale solar farm in Wayne County has been withdrawn, at least for now, after township officials determined the developer's application was incomplete.
During a special meeting Wednesday night, Damascus Township supervisors were considering a conditional use application submitted by Ampliform for a utility-scale solar facility spanning portions of Damascus and Oregon townships.
However, township solicitor Jeffrey Treat advised supervisors that the application did not include a lease agreement from the property owner demonstrating that the developer had legal authority to build on the site.
Following that determination, Ampliform withdrew its application before any vote was taken.
The proposed project would have included more than 36,000 solar panels and, according to the developer, generated enough electricity to power approximately 3,000 homes.
The proposal has drawn significant public interest and debate in recent months, with residents packing township meetings.
Opponents have raised concerns about the project's size and its potential impact on the area's rural character, wildlife habitat and forested land.
According to application documents, construction of the facility would have disturbed approximately 103 acres and required substantial tree clearing. Critics argued the proposed clearing exceeded township limits.
The withdrawal leaves the project's future uncertain, though it does not prevent the developer from submitting a revised application in the future.
The proposal had been the subject of a conditional use hearing on May 20 before Wednesday night's special meeting at the Equinunk Fire Station.
No timeline has been announced for whether Ampliform intends to refile its application.
2026 Sinclair, Inc.

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With appropriate backup power and demand side flexibility measures in place, it is both technically and economically possible for data centers to use intermittent renewables sources like wind and solar to provide continuous baseload power, according to a study by LUT University, Finland, exploring this possibility.
The study concluded that, because data centers have limited ability to adapt to fluctuations in solar generation, they must therefore have access to at least seven times their baseload operating requirements. However, such an oversized supply of solar, or wind, to ensure continuous power availability would also lead to curtailment of excess solar generation during peak production hours. In addition, even with overcapacity and battery storage, wind and solar alone cannot guarantee uninterrupted electricity supply for data centers.
Altti Meriläinen, Junior Researcher at LUT University, told pv magazine that location is a massive factor in determining whether it is cost-effective to power a data center with 100% solar and battery storage. “It depends on the location. According to a recent report by IRENA, solar PV and BESS based baseload supply can reach levelized cost of electricity (LCOE) of less than €100 ($115)/MWh in several locations around the globe,” the researcher said, referencing a recent report on the economics of firm solar and wind by the International Renewable Energy Agency (IRENA),” she stated.
The LUT University study focused on the continuous supply of 1 GW of renewable energy to two hypothetical data center scenarios in the Nordic environment – a full baseload power supply (8,760 h/a) and a scenario with full-load hours of at least 8,000 h/a, mirroring the operational characteristics of nuclear power plants.
The model the study used was an off-grid system comprising wind, solar, a battery energy storage system (BESS) and a backup power plant. Both configurations showed backup generation is crucial and the location of the renewable generation has a strong impact on the cost of supplied electricity. The LCOE at the most favorable location can be up to 24% lower than at the least favorable location, while the LCOE for the continuous full-load operation results approximately in 100 €/MWh and decreases below 80 €/MWh in the 8000 h/a scenario in the most favorable location.
The study noted that the data center chosen as the end use case represented a simplified load profile with a relatively constant power demand. The researchers did not model the detailed operational behavior of data centers, such as cooling requirements or dynamic load variations. The objective was purely to see whether Nordic environments can host renewable-powered data centers.
“We are currently preparing a project called Net Zero Energy Communities together with data center investors and operators where the analysis will be expanded and detailed by analyzing real-life cases,” said Meriläinen on future developments arising from the study.
LUT University’s Professor Samuli Honkapuro, added that the study has been discussed in major Finnish media. “We are communicating the key message to policy makers. For instance, we have discussed with a member of the Finnish parliament, who is running a legislative initiative about grid connection requirements of the data centers,” the academic told pv magazine.
Flexibility
The researchers’ work also highlighted that the operating expenditure of the backup power plant can be reduced when data centers embrace demand-side flexibility. However, engaging in demand response programs could also lead to higher curtailment of renewable generation, the study said.
In Finland, where nuclear is a big part of the energy mix, the study’s approach can offer advantages over nuclear power for data center developers, with the main bonus being shorter construction times.
“Solar energy production is highly concentrated in the summer months, emphasizing the importance of storage and balancing capacity. Although the Nordic climate imposes strong seasonal constraints on renewable generation, the results demonstrate that a renewable-based baseload system can achieve cost levels comparable with nuclear power. This finding strengthens the case for renewables as a viable baseload option even under the challenging conditions of high-latitude regions,” the paper concluded.
The study ‘Techno-economic feasibility of a renewable baseload power supply for data centers’ will appear in the journal Energy in August 2026.

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Research from Good Energy showed 91% of UK adults said they fear geopolitical instability will keep electricity prices high for a long period. 
Over half of UK homeowners are now considering solar panels as concerns about rising energy prices continue, according to analysis from Good Energy.
Research showed 91% of UK adults said they fear geopolitical instability will keep electricity prices high for a long period. 
Just 15% have solar panels installed, but 51% said recent instability increased their interest in installing them. 
Solar panel sales at Good Energy rose by 91% in February and March, with domestic customer sales hitting record levels in the second quarter. 
Search demand for solar panels jumped by 104% since January. 
Data also found that neighbour influence is affecting uptake, with 39% of homeowners more likely to install solar if others on their street already have panels. 
Goal for more this summer. Predict results, pick the winners and enter Spot the Ball for your chance to win a Sonos home cinema system worth more than £2,000, courtesy of Hampshire Trust Bank.
Carl Hogg, managing director at Good Energy, said: “In the current climate, one thing that households are looking for is certainty around their electricity bills. 
“Solar is one of the few ways people can take a bit more control, generate their own power and reduce their exposure to those global shocks. 
“We have seen this reflected in demand, with a 91% increase in sales from February to March this year.”
Hogg added: “We are also seeing how much influence neighbours have. Once a few homes on a street install solar, others start to look into it seriously. It makes it feel more normal and more achievable.
“There is still a gap when it comes to understanding how it all works, and that is something the industry needs to keep improving. But the shift is clear. 
“For many households now, they are conscious about securing energy independence.”
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The Welsh Rugby Union (WRU) has spent around £1m putting more than 3,000 solar panels on the roof of the Principality Stadium in Cardiff, describing it as a "win-win" for fans.
The WRU said the installation, which is the largest of its kind at any sports stadium in the UK, would save between £300,000 and £400,000 on energy bills every year.
At a time when the Union is under scrutiny over its plans to cut a regional rugby side, Gavin Marshall, the WRU's chief operating officer, said the investment made financial sense.
The stadium, home of Welsh national rugby, has hosted high profile gigs from the likes of Taylor Swift, Beyoncé, Oasis and Coldplay.
Tinkering with such an iconic building could be risky but the work has been done "sympathetically" according to Darren Crossman, head of facilities and safety at the stadium.
The 3,296 panels were driven through the stadium's large access tunnel, known as the Dragon's Mouth, before being placed on the covered pitch and lifted onto the roof with a huge crane and then connected, in a process which took months.
"You can't see them from the ground level but what we've tried to do is make a mirror image on both sides of the stadium so that there's nothing hideous up here," he said.
Evoenergy, the company behind the project, said it would generate enough electricity to power the equivalent of 50 match days.
The panels, covering 6000m², have been switched on since February and while direct sunlight itself is not needed for energy to be generated, the recent heatwave gave the "best couple of weeks".
"We were generating in excess of 800 kilowatts," said Darren.
"So the stadium was actually off-grid for most of the day, during the day, and exporting power as well, which is something we hadn't actually dreamed of being able to do."
The union believes the technology could pay for itself quicker than the three-four years originally projected.
"The results have been have been great and we'll get payback within two to three years for the investment we've made," said Gavin, adding that hundreds of thousands of pounds saved on energy bills would be "reinvested back into Welsh rugby."
"It's a win-win from a financial and an environmental perspective," he said.
An increasing number of sporting venues have already added solar panels to their buildings, including the London Stadium and the grandstand at Ascot Racecourse.
The power station was completed in 1964 and has been a landmark in the Vale of Glamorgan for decades.
Six of the new chicks are from two pairs who can be seen at a centre in north Wales.
Police are searching a 150 acre area at a fuel briquetting plant after arresting a 41-year-old.
John Bishop's ashes were scattered by Gwent Crematorium without permission and in the wrong place.
It is the only house left in Troedrhiwfuwch village and auctioneers have set its guide price at £35,000.
Copyright 2026 BBC. All rights reserved. The BBC is not responsible for the content of external sites. Read about our approach to external linking.
 

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Float solar array legislation passes state Senate, fails to advance past committee in Assembly  North Country Now
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For decades, conventional power plants have been the backbone of India’s electricity system. Coal-fired generation has provided the stability and reliability needed to support industrial growth, urbanization, and economic development. However, the energy landscape is rapidly changing. With renewable energy becoming increasingly affordable and battery storage technologies advancing at an unprecedented pace, India is now exploring a crucial question: Can solar plus storage replace conventional power?
The answer is increasingly shifting from “someday” to “soon.”
India has set an ambitious target of achieving 500 GW of non-fossil fuel capacity by 2030. While solar energy has become one of the cheapest sources of electricity generation globally, its intermittent nature has historically limited its ability to replace conventional power entirely. Solar generation peaks during daylight hours, while electricity demand often extends well into the evening.
Battery Energy Storage Systems (BESS) are changing this equation.
By storing excess solar energy generated during the day and discharging it during evening peak demand, battery storage enables renewable energy to become dispatchable. This capability is critical for providing round-the-clock (RTC) power, a requirement traditionally met by thermal power plants.
The economics are also becoming increasingly compelling. Utility-scale battery prices have declined significantly over the past decade, while solar tariffs in India continue to remain among the lowest in the world. Together, solar and storage are creating a powerful combination capable of delivering reliable power at competitive costs.
India’s policymakers have already recognized this potential. Recent renewable energy tenders increasingly incorporate storage requirements, and several RTC renewable energy projects have demonstrated that clean power can be supplied consistently throughout the day. These projects combine solar, wind, and battery storage to ensure uninterrupted electricity delivery while reducing dependence on fossil fuels.
Beyond environmental benefits, RTC renewable energy offers strategic advantages for India’s energy security. The country imports a significant portion of its fossil fuel requirements, making it vulnerable to global commodity price fluctuations. Expanding domestic renewable generation paired with storage can help reduce import dependence while stabilizing long-term electricity costs.
For commercial and industrial consumers, the benefits are equally compelling. Businesses are facing rising electricity tariffs, demand charges, and increasing pressure to meet sustainability commitments. Solar-plus-storage solutions enable companies to manage peak demand, improve power reliability, and lower operating costs while reducing carbon emissions.
However, replacing conventional power entirely will not happen overnight. Grid modernization, storage deployment, transmission upgrades, and supportive market mechanisms will all play critical roles in the transition. Coal-based generation will continue to serve as a balancing resource in the near term, particularly as renewable penetration rises.
Yet the direction of travel is clear. Renewable energy is no longer competing solely on sustainability credentials. It is increasingly competing on reliability, flexibility, and economics.
The future of India’s power sector will not be built on a choice between conventional and renewable energy. Instead, it will be shaped by intelligent integration of renewable generation, storage systems, and digital energy management technologies.
As storage costs continue to decline and deployment accelerates, solar-plus-storage is poised to move from being an alternative energy solution to becoming a mainstream source of reliable power. The question is no longer whether solar and storage can replace conventional power, but how quickly India can scale the infrastructure required to make that transition a reality.
The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine.
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From pv magazine Germany
Germany’s Fraunhofer Institute for Solar Energy Systems ISE announced it was able to increase the power conversion efficiency of its record-breaking III-V germanium solar module from 34.2% to 34.4%.
“Compared to the previous record of 34,2% the thing we changed was the layout,” Fraunhofe ISE scientist Laura Stevens told pv magazine. “We used the same cell technology and the same front side glass type. The first module had shingle strings and in the second, better module we connected the cells in a shingle matrix.”
The result was achieved using “shingle-matrix” technology in combination with space-grade solar cells, the German institute said. The previous record of 34.2% was set earlier this year using an 833 cm² module also based on space-grade solar cells from Azur Space. For the latest development, the cell manufacturer adapted its triple-junction solar cell technology to the terrestrial solar spectrum. The anti-reflective front glass structures used for the module were supplied by Temicon.
A key factor in the new record is the use of shingle-matrix technology for interconnecting the solar cells. Developed by Fraunhofer ISE in cooperation with a mechanical engineering partner, the approach is now also used in commercial module manufacturing. The solar cells are cut into narrow strips, arranged in an overlapping shingle pattern, and bonded with electrically conductive adhesive (ECA). This enables direct cell-to-cell contact, eliminates solder-coated copper ribbons, reduces shading, and increases active area utilization.
In July 2025, Fraunhofer ISE achieved 40% efficiency for an indoor III-V solar cell based on an indium gallium phosphide absorber.
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Big Read
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Singapore basks in year-round sun, yet only around 8 per cent of landed homes and condominiums have installed solar panels as of 2025. As costs fall and technology evolves, what will it take for residences and businesses to make the most of what’s shining down on them?
The cost of installing solar panels has fallen drastically with technological advancements over the past decade, and interest among private homeowners and business is growing in Singapore. (Illustration: CNA/Clara Ho)
This audio is generated by an AI tool.
Step into Mr Goh Jing Hwee’s house and you will be greeted by an array of installations that harness the power of the sun. 
Solar-powered clip-on lights line the stairway, solar-powered bollard lights dot the garden and 60 solar photovoltaic (PV) panels cover the roof of his residence. 
When the 63-year-old semi-retiree rebuilt his home in central Singapore in 2021, he designed a flat roof specifically for a solar panel system that cost around S$30,000. 
Almost a decade before that, a much smaller solar panel system had cost him three times as much.
“In 2012, when I put the solar panels, it was very expensive … (Now) the cost has gone down by as much as 60 to 70 per cent,” Mr Goh said, adding that he expects to recoup his investment in about eight to nine years. 
On an average day, around 60 per cent of what his rooftop system generates covers all his household’s daytime electricity usage, with the excess electricity generated sold to Singapore’s national power grid. 
The falling costs and improving efficiency have made solar solutions an easy sell for homeowners such as Mr Goh and businesses grappling with rising electricity bills. 
When Mr Eu Jun Hao, manager at Oriental Aquarium, was planning to move his aquatic plant farm from Lim Chu Kang to Sungei Tengah seven years ago, he anticipated that his electricity usage would surge as he modernised production techniques. 
The farm’s water recirculation system in the new semi-controlled greenhouse would require more electricity than his previous site, where plants were grown in the open air.
The 429 installed panels have since cut his electricity bill by around 40 per cent compared to buying fully from the national power grid, his provider Union Energy stated.
Mr Eu is on a 14-year power purchase agreement, a long-term contract in which a solar provider finances, installs and maintains a solar energy system. The property owner avoids a high upfront cost and buys the generated electricity from the provider at a fixed rate.
“We were glad that we made this choice when we saw the substantial savings, especially in the current climate’s electricity prices,” Mr Eu said. 

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In response to queries from CNA TODAY, Ms Violet Chen, director of solar and grid solutions at the Energy Market Authority (EMA), said that solar deployment among private commercial, industrial and residential users has seen strong growth. 
Private sector solar deployments have risen from 1,489 in 2021 to 2,321 in 2025 – a 2.5-fold increase in total installed capacity. 
Separately, the total installed capacity of solar PV installations has expanded almost five-fold for private residences – including landed properties and condominiums – from 1,749 installations in 2021 to 6,912 in 2025. 
In response to CNA TODAY’s queries, the Housing and Development Board (HDB) said that it has installed solar panels on around 5,300 housing blocks, or half of all HDB blocks, as of December 2025. 
This represents a solar capacity of 455 megawatt-peak (MWp) across its estates, equivalent to powering about 114,000 four-room flats.  
“The solar energy harnessed is first used to power common services, such as lifts, lights and water pumps in the day, with excess energy channelled back to the grid,” HDB said.
Solar firms reported a steady climb in demand from private homeowners and businesses seeking to guard against rising electricity tariffs, particularly over the past three months since the Iran war began. 
For PMCE Global, its founder and director Satish Prasath said that his firm completed a record 80 solar installation projects in April alone. 
Where the company handled around 24 projects in its first year a decade ago, it now completes roughly 400 a year, with residential clients making up about 85 per cent of the business.
Yet, despite the momentum, solar adoption remains far from mainstream in Singapore.
Figures from the Singapore Department of Statistics showed that there were 69,200 landed properties in 2025. 
In parliament in May, Minister of State for Trade and Industry Gan Siow Huang said that around 8 per cent of all private residential buildings – or landed properties and condominiums –  have installed solar panels.  
Among condominiums, less than 2 per cent of the management corporation strata titles (MCSTs) have solar panels installed. This was based on the Building and Construction Authority’s 2026 public consultation on proposed areas of review for the Building (Strata Management) Act.
In a country drenched in sunshine year-round, technological innovations and new financing models have made the case for solar stronger – and cheaper – than ever. 
However, would-be adopters still run headlong into various anxieties, red tape and the stubborn reality of a land-scarce nation.
So what will it take for Singapore’s homes and businesses to step into the light truly – and for one of the world’s sunniest cities to make full use of its most viable renewable energy source?
Being close to the equator and with very little seasonality, Singapore enjoys strong, relatively consistent sunshine year-round.
However, one major challenge is the lack of land compared to countries such as Australia, where vast rural expanses are well-suited for sprawling solar installations. 
Still, Singapore does have substantial “built surface area” to host solar panels – namely, rooftops, building facades, carparks and infrastructure corridors. This was the view of Mr Rob Jones, renewable energy leader at risk advisory firm Marsh Asia.
The cost of installing solar panels has also dropped significantly in the past decade, driven in part by technological and manufacturing advancements, particularly in China, the now undisputed leader in solar PV production.
Dr Thomas Reindl, deputy chief executive officer of the Solar Energy Research Institute of Singapore (SERIS) at the National University of Singapore (NUS), noted that solar electricity can now be generated at 7 cents to 13 cents per kilowatt-hour (kWh), depending on the size and complexity of the installation. 
“This compares to around 30 cents per kWh that households pay in Singapore right now, so solar power is less than half of what we pay for electricity,” he said.
Thus, the government does not subsidise residential rooftop solar panels, because economic conditions are “very favourable” for property owners to consider installing them, Ms Gan told parliament in May. 
She also said that eligible private buildings may tap the Green Mark Incentive Scheme for Existing Buildings 2.0 to obtain grants and lower the upfront cost of energy improvement works, including solar panel installation.
Mount Elizabeth Hospital is among the businesses that have embraced solar power. 
It installed 381 solar panels as part of a major campus overhaul, which was unveiled in April this year. They are positioned above selected wards to power the hospital’s public and common areas. 
The installation is projected to generate around 1.4 million kWh of electricity yearly, reducing the amount of electricity needed to be bought from the national power grid. 
Ms Lim Xueni, the hospital’s director of operations, said the upgrade was driven by sustainability goals, rising electricity tariffs and the support of government policies, including green loans. 
Solar financing models have also advanced. Mr Lim Wen Bin, a partner in infrastructure advisory at consultancy KPMG in Singapore, said that these offer clients a choice to avoid a large capital expenditure up front.
One company behind such new financing models is GetSolar, one of the first firms to launch the rent-to-own model for solar panels in Singapore, promising its clients zero upfront cost, zero hassle and savings from the start.
Ms Kimberly Hoong, the firm’s residential sales lead, said: “Instead of having to pay one big lump sum upfront for a solar panel system … we remove that high upfront cost, and we also service our customers for the next five to 10 years.” 
Under its 10-year plan, customers pay nothing upfront and instead pay a fixed monthly fee, not tied to an interest rate, which is typically lower than their monthly electricity savings. 
A shorter five-year plan lets customers pay 50 per cent upfront for those who want to own their system sooner or reduce their total lifetime cost.
For Mr Ma Chin Chew, owner of N&N Agriculture, a pioneer of pasteurised egg production in Singapore, harnessing sunlight is crucial for his farm in Lim Chu Kang, especially since he plans to expand his fleet of electric delivery trucks. 
“Currently, all the (hen) houses are closed houses, so they depend very much on ventilation fans 24/7. We have about 18 houses, so it’s a high-energy-usage business. 
“We also have egg processing and a feed mill using a lot of power.” 
In 2018, Mr Ma spent more than S$600,000 to install a roughly 400 kWp system on one roof, but poor after-sales service left a faulty inverter unrepaired for nearly two years, with hefty service charges to boot. 
He thus switched to a 2 MWp system under a power purchase agreement with Union Energy, which locked in electricity costs at a negotiated long-term rate. 
He estimated that he now saves around S$45,000 a month with a 25 per cent reduction in his electricity bill, which amounts to around half a million dollars in savings a year.
Over at Boathouse Residences, Mr Mohd Rizal Abdullah from its managing agent RealtyLink Consultancy said that the shorter return-on-investment period for solar installations and the increasing volatility of energy market prices made adopting solar power not only an “environmentally responsible option, but also a financially strategic one”.
The condominium is now on a lease model and pays a fixed monthly fee of S$7,400, excluding Goods and Services Tax, to the vendor. It has been consuming about 180,000 kWh less electricity from the national grid since the installation in March 2025.
Despite improvements in the economics of solar power, users looking to make the switch often find the path fraught with obstacles.
Even institutions that have committed to solar energy find their ambitions bumping up against practical constraints. 
At Mount Elizabeth Hospital, rooftop real estate must be shared with air-conditioning and mechanical ventilation infrastructure.
Ms Lim, its director of operations, highlighted the physical space limitations, upfront capital required and a lack of expertise in evaluating and monitoring solar projects after installation as key barriers to solar adoption among businesses.
Another common sticking point for businesses is the mismatch between a solar contract’s lifespan and a company’s lease. 
Given that a power purchase agreement typically runs from 10 to 20 years, Ms Ellen Teo, chief executive officer of Union Energy, said that companies without security of tenure over that period may baulk at signing on for solar power.
Roof condition is another barrier, because some businesses have to take on six-figure refurbishment costs before panels can even be installed. 
For small- and medium-sized enterprises, another wrinkle is persuading older business owners to commit to a 15-year contract when succession planning is already a concern. 
Ms Teo said that Union Energy tries to work around these constraints by offering shorter-term arrangements at higher rates, which still provide savings compared to electricity tariffs, or by structuring re-roofing solutions into solar packages for buildings with ageing roofs. 
And then, there are condominiums and multi-tenant commercial buildings, which face even more complex hurdles.
Unlike landed homes, these buildings have master meters that record overall electricity consumption, while sub-meters track individual units or tenants. 
Under this metering arrangement, the figure for common services consumption is derived by subtracting the sub-meters’ readout from that of the master meters.
“This sub-metering arrangement under the existing system could result in billing errors that affect residents and tenants when excess solar power is exported to the grid,” Ms Chen from EMA said. 
In practice, this means that solar energy generated on-site is generally used to offset electricity consumed at shared facilities, and excess energy cannot be sold back to the grid.
However, Ms Chen said that national grid operator SP Group is working on a set of complex system changes to address this. 
She suggested that building managers can handle their solar output carefully to avoid billing complications.
Alternatively, SP Group offers a direct-to-grid connection option, where the solar system connects straight to the national grid and bypasses the shared meter entirely. This has been successfully rolled out at business park Midview City in Bishan. 
There is growing interest among condominium managers and residents to adopt solar panels, but there are hoops to jump through before such moves can be made, Dr Rex Yeap said.
He is vice-chairman of The Interlace condominium’s MCST and vice-president of the MCST Association of Singapore.
For example, the MCST of each condominium would have to iron out details such as how liability might be split between the vendor and the MCST in the event of a potential roof leak. 
They might also have to contend with narrow rooftops that make installing solar panels on many condominiums commercially unviable. 
The slow process of seeking approval to install solar panels in condominiums through annual general meetings – which can take up to a year – for a relatively small system may also be a deterrent for some larger solar firms, Ms Teo from Union Energy said. 
“Condominiums are a growing but very complex segment … (they are) largely governed by MCSTs, which require longer gestation periods for projects to float, so not many solar installers would find it very worthwhile supporting this segment,” she added.
In 2025, Singapore crossed its initial “2 gigawatt-peak by 2030” national target for solar power generation, equivalent to generating enough energy to meet the annual electricity needs of around 350,000 households.
Since then, it has raised the official national target to 3 gigawatt-peak by 2030, under the Singapore Green Plan. 
This amount of solar energy can generate 2,800 GWh of electricity a year, enough to power about half a million households in the same period, Ms Chen from EMA said. 
And there is indeed plenty of room for growing Singapore’s solar energy generation.
Mr Jotham Chan, head of residential from renewable energy and clean infrastructure solutions provider Eigen Energy, noted that although public infrastructure led the first wave of adoption, thousands of prime rooftops across commercial zones and landed housing estates remain completely untapped. 
His colleague, Mr Pradhan Rajoo, said that as solar energy becomes more widely accepted and proven, customer priorities have also shifted.
From initial concerns centred on unfamiliar technology, system reliability and long payback periods, the focus has shifted to aesthetics, roof compatibility and alignment with long-term property plans. 
Mr Rajoo, who is business development manager for commercial and industrial sectors at Eigen Energy, added: “Ultimately, the next phase of market growth will depend on how easily we can bring zero-upfront financing to the masses and maximise trickier roof spaces, turning solar panels into a standard, everyday feature for homes.”
Overcoming obstacles to the broader adoption of solar energy and boosting Singapore’s solar power generation is not just a matter of lowering costs and clearing red tape.
It is also about transforming solar infrastructure, analysts said. 
Dr Reindl from SERIS said that Singapore will have to “think out of the box”, such as embracing floating solar panels on water bodies, for example, the 60-MWp floating solar power plant on Tengeh reservoir.
“Apart from inland reservoirs, we can also imagine floating solar in near-shore areas that are away from shipping routes and nature-protected areas.”  
National water agency PUB has installed about 67 MWp of solar capacity, through rooftop PV systems at six facilities and floating PV systems at three reservoirs.
There are plans to deploy future large-scale floating solar PV systems at  Lower Seletar Reservoir and Pandan Reservoir.
The 60-MWp floating PV system at Tengeh Reservoir, which began operations in 2021, consists of about 122,000 solar panels spanning 45 hectares, generating enough clean energy to power around 16,000 four-room HDB flats.
Trials at the Tengeh Reservoir in 2016 saw floating PVs performing 7 per cent to 10 per cent better than typical rooftop systems, partly due to the cooler water surface and reduced shading. 
Since the rooftops of older HDB blocks were not originally designed for solar installations, retrofitting works had to consider optimal panel placement and wiring, without obstructing essential block services.
Since May 2017, HDB has introduced solar-ready roofs for all new public housing blocks where feasible, incorporating features such as dedicated trunking, integrated support structures and service access routes on the roof, so that solar panels can be easily mounted and maintained.
In the meantime, novel technologies such as ultra-lightweight “solar films” could unlock surfaces and structures previously unsuitable for solar, the experts said.
“Suddenly, we can imagine that we have very large over-arching canopies that stretch over areas such as car parks, flood canals or even the very large port areas, Dr Reindl said. 
“One day, maybe we can even over-arch HDB blocks with solar canopies, which would also provide shade for the residents.” 
At JTC, the industrial developer’s SolarLand programme uses a flexible procurement approach that enables it to harness industrial land parcels earmarked for future deployment for solar generation.
As of the first quarter of this year, 927-MWp solar capacity has been deployed across JTC buildings, vacant industrial land and its privately leased industrial properties – equivalent to powering more than 216,000 four-room HDB flats yearly. 
The agency has launched a tender to develop Singapore’s first overhang solar PV system in Woodlands to harness void spaces between multi-storey industrial buildings.
Though such technologies may take a while to become commonplace, many businesses are studying new solar solutions as they mature. 
In public housing, HDB is testing vertical solar PV panels integrated into the roof fascia at Parc Clover@Tengah and Parc Residences@Tengah.
At resort island Sentosa, the Sentosa Development Corporation (SDC) has deployed PV cells across 40 rooftop spaces alongside efforts to achieve carbon neutrality by 2030. 
Mr Kelly Yoong, SDC’s divisional director of corporate planning and development, said the programme has doubled initial targets, achieving a total solar capacity of 6 MWp, which would offset the carbon emissions from 100,000 hotel room-nights.
Sentosa is also exploring innovative technologies such as Building Integrated Photovoltaics and solar pavements, Mr Yoong added.
Some companies are also offering innovative solar solutions for households’ daily use, even if larger solar PV systems may be out of reach. 
Mobile clean energy battery technology company Go Rental offers solar-powered battery and energy storage systems geared towards homes, businesses and events such as Formula One motor racing. 
The firm’s founder and managing director Colin Peh has seen demand for renting and buying basic mobile systems rise 40 per cent over the past six months, including from residents living in HDB flats. 
A solar energy system, comprising a one-kilowatt solar panel and a one-kilowatt battery, costs around S$2,000, and the stored energy can power a fish tank, charge a laptop or run a fridge.
“We also provide bigger solar panels and home systems, but what we see a huge increase in is people buying for smaller use, for a little bit more resilience,” Mr Peh said.
One key area for growth would be the broader deployment of energy storage, for grid-scale batteries and behind-the-meter systems to manage intermittency, reduce curtailment risk and increase the reliability value of solar, Mr Jones from Marsh Risk said. 
A partnership between EMA and SP Group saw Singapore deploy its first utility-scale energy storage system at a substation in October 2020, with a capacity of 2.4 MW.
A solar forecasting model that anticipates solar power output in advance to manage intermittency issues was also rolled out through a S$6.2 million research grant awarded to a consortium led by NUS. 
However, better technology may not automatically translate into buy-in.
Those who made the switch to solar power said the decision was not simple, even though costs declined and solar panel technology improved.
Some homeowners told CNA TODAY that they would only reconsider installing solar panels if there were substantial government subsidies to shorten the break-even period to around two to three years, given the costs they might incur to renovate their old rooftops. 
Mr Goh the semi-retiree said the orientation and condition of a roof can significantly affect what a system can generate, adding that government subsidies could perhaps help nudge more homeowners over the line.
Given the favourable orientation, height and flat surface area of his rooftop, he captures sunlight from early morning to afternoon. 
Hence, Mr Goh is keen to explore opportunities to store all the generated energy – rather than sell it back to the national grid – to cover his nighttime electricity usage. 
Dr Yeap from The Interlace condo said more financial support from the government or solar companies to commission feasibility studies for an estate’s rooftop capacity, structural stability, electrical integration, fire safety and expected system yield could make solar energy more attractive. 
Mr Mohd Rizal from RealtyLink Consultancy, which manages 60 properties in Singapore, suggested reducing the level of condominium resident support required for approving solar installations, from a special resolution to an ordinary resolution – as was done for electric-vehicle charger installations.
Greater access to battery energy storage systems would help condominiums optimise solar use and better support growing demand for charging e-vehicles. 
“Overall, the appetite for solar power in the residential sector is growing,” Mr Mohd Rizal said.
“What is needed now is a more enabling ecosystem – one that combines regulatory support, practical financing and clearer implementation pathways – to help more condominiums make the transition with confidence.” 
Even with all these ongoing hurdles, Singapore’s solar capacity growth has exceeded expectations so far. 
The experts noted that its solar ambitions could hit a hard ceiling due to limited land and suitable surfaces for solar deployment. 
In the 2020 Update of the Solar PV Roadmap for Singapore by SERIS, it was estimated that if all suitable areas for conventional solar panels were used, the total techno-economic potential is as high as 8.6 gigawatt-peak.
Ms Chen from EMA acknowledged that although solar energy is now the main source of renewable energy that can be harnessed domestically, it could at best meet around 10 per cent of the country’s projected energy needs by 2050. 
“Singapore will therefore need to continue to pursue other decarbonisation pathways,” she said.
Ms Linda Zeng, a senior analyst in power and renewables at BMI, a unit of credit risk analysis firm Fitch Solutions, said that the economics are much more attractive for solar energy as costs have declined, with payback periods as short as four years. Based on BMI’s forecasts, solar energy would make up around 5 to 6 per cent of the power mix by 2030. 
In the next 10 to 20 years, the needle will not move much in terms of solar power, playing a limited role in meeting Singapore’s energy needs, she said.
“This is why we’re actively exploring alternatives, including next-generation nuclear, geothermal and electricity imports, all of which are scalable,” Ms Zeng added. 
If solar power were to be a larger part of Singapore’s energy mix, Mr Lim from KPMG said it would boil down not only to maximising domestic capacity, but also to importing electricity generated from clean sources from neighbouring countries. 
“Therefore, the subsea high voltage cables will be very critical. 
“The ASEAN power grid will be a very important part of the agenda, and allow lower-cost renewables like solar to be a bigger part of our energy mix.” 
And although it may not be fair to pit Singapore against land-rich countries, comparisons with other dense urban landscapes could prove instructive.
Ms Zeng said that Singapore’s solar density is the highest in ASEAN, at around 0.35kW per capita. This is more than 10 times higher than Hong Kong’s.
Mr Prasath from PMCE Global said demand for solar solutions is in a “slow growth” phase, but in his experience, one satisfied customer tends to bring in four more through word of mouth. 
“Even if the energy crisis (settles) … there will still be a huge demand for solar power … because Singapore needs to be energy-independent.” 
Dr Reindl from SERIS said that Singapore has already installed more than 2 gigawatt-peak of solar systems and this is no small feat for a city only 725 square kilometres in size. 
“We are very likely the most ‘solar-dense’ city in the world. 
“Over time, Singapore is likely to become a global leader in ‘urban solar’, utilising every available space in a highly innovative way.”
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Bluebird Solar Launches 630Wp N-Type TOPCon Bifacial Module for Utility-Scale and Commercial Solar Projects  SolarQuarter
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Chinese PV module maker Astronergy, a unit of the Chint Group, has unveiled its new Astro N8 Pro series at SNEC 2026 in Shanghai last week.
The new series includes two formats. The CHSM72N version offers a power output of 800 W to 825 W, with module efficiency of up to 24.4%. The CHSM66N version is rated at 740 W to 760 W, with a maximum efficiency of 24.5%. The modules measure 2,595 mm × 1,303 mm × 33 mm and 2,384 mm × 1,303 mm × 33 mm, respectively.
Astronergy said the Astro N8 Pro series is based on its TOPCon 5.0+ technology platform and incorporates 210 mm wafers, quarter-cut cells, high-density encapsulation, and multi-busbar technology. According to the company, the design is intended to increase module power while reducing hot-spot risk, improving reliability, and lowering balance-of-system costs for utility-scale and distributed PV projects.
According to the company’s product information, the modules have a bifaciality factor of around 85% and a power temperature coefficient of -0.26%/C. The series supports system voltages of up to 1,500 V DC and offers a positive power tolerance of 0 W to 3 W. Astronergy said the product is designed for high-output applications where land use, string design, and lifetime energy yield are key considerations.
The company also highlighted the series’ long-term performance. The Astro N8 Pro modules are backed by a 15-year product warranty and a 30-year linear power warranty. First-year degradation is specified at no more than 1%, followed by annual degradation of no more than 0.35% from the second through the 30th year.
The 72-cell-format version features an anti-dust frame design aimed at applications where soiling losses and cleaning costs can affect project economics. Astronergy said the design is intended to reduce power losses caused by dust accumulation and deliver additional energy generation gains of around 2% to 6%, depending on site conditions.
Astronergy President Lu Chuan said the Astro N8 Pro series reflects the company’s long-term development of n-type technology and system-level optimization.
At SNEC 2026, the company also showcased the Astro N8, a 745 W module for utility-scale solar projects; the Astro N7 Pro, based on TOPCon 5.0+ technology and a quarter-cut cell design; and upgraded Astro N7 3.0 and Astro N7s 3.0 products for differentiated applications.
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US President Donald Trump would have everyone believe that coal power is the best idea since sliced bread, but the the facts keep getting in his way. Coal is inevitably succumbing to the march of historical irrelevance and renewables are rising, particularly in the case of solar power. In the latest news, a new solar cell manufacturing operation is cranking up to full speed in the City of Cartersville, Georgia.
With so many solar factories coming to the US in recent years, another one is not particularly big news. However, this one is newsworthy from a size perspective. The firm behind the news is the US branch of Korea-headquartered Qcells, which is a bigger-is-better newsmaker unto itself.
Back in 2023, the company described how it planned to make the largest clean energy investment ever made in the US, with Georgia the focus of attention. The result is Cartersville, where Qcells has been manufacturing solar modules from solar components made elsewhere. As of June 9, the campus is now home to a solar cell fabrication facility, making Cartersville “America’s first and only vertically integrated solar factory” as described by Qcells.
As is common practice in the solar industry, the Cartersville plant was producing solar modules (the step between solar cells and solar panels) with cell components made elsewhere. Now the campus is a vertically integrated, Made-in-the-USA facility. At full capacity, it will turn out solar ingots, wafers, and cells at the rate of 3.3 gigawatts each per year.
The solar cell end of the operation is up and running at partial volume, with full capacity expected in Q3. Qcells also reminds everyone that it recently expanded its Dalton factory in Georgia. Between the two factories Qcells expects its cumulative capacity to reach 8.6 gigawatts per year, the equivalent of 47,000 panels per day.
The Made-in-the-USA element is a also a significant development because it represents the ability of some domestic industrial sectors — though not coal — to rebuild. The US once dominated solar manufacturing globally, after Bell Labs introduced the first practical silicon solar cell at its New Jersey campus in 1954. However, Japan and other nations quickly caught on, particularly China. By the turn of the century, the domestic industry was practically dead in the water.
The turnaround began with a healthy assist from US taxpayers during the Obama administration, with a soup-to-nuts effort to bring the installed cost of solar energy down to parity with fossil fuels.
Taxpayer support has continued through to the present day, including tax law that favors domestic content. The new facility enables Qcells to claim all-domestic content for its Cartersville modules, making it eligible for Section 45X manufacturing tax credits that apply to each stage of the fabrication process, from ingots, wafers, and cells to the modules themselves.
Qcells emphasizes that it is the only solar manufacturer in the US with that capability.”The Cartersville factory is the first such operation built in the United States in more than a decade and will be home to the largest ingot and wafer plant ever constructed in the country,” the company states.
If you know otherwise, drop a note in the comment thread. Assuming Qcells really is the one and only, the firm is looking forward to a competitive advantage from a chain of tax credits that will support future growth past its current 8.6-gigawatt output.
Qcells also takes note of the benefits of its Made-in-the-USA model on the solar power plant side. Developers have been parking solar panels in the ground and on rooftops at a white-hot pace, regardless of the sharp U-turn in federal energy policy. Meanwhile, despite Trump’s efforts to rebuild the domestic coal industry, the output from coal power plants slipped behind utility-scale solar in May. That marks the first month solar outran coal, and it won’t be the last.
The tax advantage of domestic-content solar modules lends further support to the pace of solar development. As Qcells points out, under current tax law its Cartersville modules will help qualify developers qualify for a 10% domestic content bonus. Qcells also takes note of additional advantages:
A fully integrated domestic facility shields customers from supply chain disruptions.
Information about sourcing, pricing, timelines for delivery is more accessible and transparent.
Exposure to overseas supply issues is reduced.
Exposure to tariff volatility is also reduced.
That last item is a rather mild way of referring to the President’s willy-nilly and ofttimes illegal tariff declarations. If you have any thoughts about that, drop a note in the discussion thread.
President Trump swept into office last year determined to stamp out both wind and solar power. Why? Who knows! Everyone else knows that wind and solar are by far the most economical, and the quickest ways to feed more electricity to a hungry population.
Federal energy policy aside, the decline of coal is written on the wind, so to speak, with industry analysts drawing attention to structural issues. The outsized expense of building, operating, and maintaining coal power plants is just part of the problem. The cost of upgrading coal mines to increase domestic production also factors in, along with the cost of procuring the modern mining equipment needed to increase production. Shortcomings in the nation’s freight rail system are already impeding some coal deliveries, creating a bottleneck that limits future growth. An ongoing labor shortage has been bubbling up, and the impact goes beyond struggles to recruit more coal miners. The supply of professionals who know how to build and repair coal power plants is dwindling, too.
Meanwhile, the US solar industry is firing away on all cylinders. In addition to the news from Qcells, earlier this week the US manufacturing branch of Japan-based Toyo Solar announced that it will expand its solar operations in Texas with the addition of a new $357 million HJT (heterojunction technology) solar cell line, representing another step in an ongoing series of technology improvements that cut costs and boost efficiency.
Yesterday, TOYO also nailed down two supply agreements with two major developers, totaling $185.6 million combined.
“The multi-million-dollar commitments highlight growing commercial demand for TOYO’s solar modules, which are engineered to offer superior power output, low degradation rates, and optimized levelized cost of energy for large-scale assets,” TOYO explained in a press statement emailed to CleanTechnica.
“Utility-scale buyers are increasingly prioritizing transparency, execution track record, and strict regulatory compliance,” the company also emphasized.
The “strict” in that statement includes supply chain regulations that motivate TOYO and other US producers to avoid China as a source. More specifically, according to the company:
“FEOC-Compliant Manufacturing: Production will be executed across TOYO’s designated manufacturing footprint, supporting customer compliance requirements and positioning the final products to align with evolving domestic content and FEOC (Foreign Entity of Concern)-compliance guidelines favored by U.S. project financing sources.”
“All modules delivered under these contracts will utilize TOYO’s established non-Chinese wafer sourcing channels,” the company affirms, while underscoring the reduced risks including less exposure to “evolving tariff frameworks.”
Again, that’s rather polite way of describing the decision-making process of a US President whose decisions are routinely struck down by federal judges, but so be it.
No word yet on the names of the two developers. TOYO expects to see its solar cells distributed among Texas, New York and Maine, so stay tuned for more news from those quarters.
Photo: With the addition of on-site solar cell fabrication, the US branch of Qcells has achieved full, vertical, Made-in-the-USA status for its solar factory in Cartersville, Georgia (cropped, courtesy of Qcells).
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Equipment choices that looked like an easy win a few years ago may not save nearly as much now.
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Going solar remains one of the best ways to save money on home energy, especially in a high-cost market such as San Diego.
One homeowner recently described a last-minute cancellation with Sunrun and asked neighbors whether solar still makes financial sense under California’s newer rules.
In a recent Reddit thread, a San Diego-area homeowner said, “Managed to cancel SunRun before they began installations on Friday after my dad signed with them a few days ago.”
The homeowner’s questions covered everything from monthly savings and return on investment to battery choices, military-related housing considerations, and whether lower usage changes the value of a system.
Want to go solar but not sure who to trust? EnergySage has your back with free and transparent quotes from fully vetted providers in your area.
To get started, just answer a few questions about your home — no phone number required. Within a day or two, EnergySage will email you the best options for your needs, and their expert advisers can help you compare quotes and pick a winner.
Commenters in the area largely agreed that solar still makes sense there, but California’s current rules have changed how homeowners need to think about it. Advice from a knowledgeable source, like EnergySage, can make all the difference. This service offers free tools to help you get and compare quick solar installation quotes.
Under NEM 3.0, exporting excess electricity to the grid earns much smaller credits than it once did.
One commenter put it bluntly: “You’re gonna require a battery.”
Another added, “Good move canceling the contract before installation and taking the time to do your homework.”
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The thread also included warnings about leases and power purchase agreements, with several people saying a purchased system combined with battery storage tends to produce a stronger payoff over time.
With SDG&E prices already sitting near the top of the national range, a poorly planned solar deal can be costly. Equipment choices that looked like an easy win a few years ago may not save nearly as much now if storage is left out.
A big issue is when rooftop systems make power versus when households need it. Solar production is strongest around midday, but if no one is home to use that electricity and it gets sent to the grid for a low credit, homeowners may end up buying back more expensive power later in the day.
That makes right-sizing even more important for households with lighter or less consistent demand, including the military-and-room-rental situation mentioned in the Reddit post.
💡Go deep on the latest news and trends shaping the residential solar landscape
As one commenter wrote, “Never feel rushed to sign.”
There is also a climate benefit when solar is set up well. Using more of your own clean electricity at home can reduce reliance on fossil-fuel-heavy grid power.
If you’re shopping for solar, begin with a year’s worth of electric bills and compare offers from multiple installers. For each quote, ask how much power the system should produce, how much of that output you can realistically use as it is generated, and whether a battery is being included because it improves savings or simply makes the proposal look better on paper.
Adding battery storage to a solar setup is one of the best ways to protect your home during outages, save money on energy, and go off-grid.
In California, batteries can also help you keep and use more of the electricity your panels produce instead of sending it back to the grid for a low credit.
EnergySage’s free services can help you plan your solar installation and choose the right provider for you. With its help, you can save as much as $10,000. Its state-by-state mapping tool not only displays the average cost of solar panels in your region, but also the incentives available to offset that cost. 
If you’re looking to add a battery to increase independence and resilience, enhance your savings, and even go off-grid, EnergySage can also help with that. Its resources include information on batteries and estimates for battery installation.
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Meta has announced a new partnership to develop a solar plant in Freestone County, Texas, according to a report from Construction Digital.
The collaboration with Zelestra, a global renewable energy company, involves a power purchase agreement for the 180 MWdc (140 MWac) Palmera solar plant. This agreement continues the existing energy relationship between the two companies.
Amanda Yang, Meta’s Head of Clean and Renewable Energy, stated that the company is dedicated to adding new renewable energy to the grid and that the expanding relationship with Zelestra helps achieve that goal at scale. She noted that these projects advance energy objectives, create jobs, and deliver long-term value in the communities where they operate, demonstrating the results of strong partnerships.
The Palmera solar plant is intended to support Meta’s sustainability mission by strengthening the electrical grid with entirely carbon-free energy.
This development follows previous successful infrastructure projects between Meta and Zelestra, including the 200 MWdc Reclamation Solar Project in Indiana and the 176 MWdc Skull Creek Solar Plant in Anderson County, Texas, both backed by Meta’s PPAs. These combined initiatives are expected to create approximately 400 jobs, adding to the existing 81 MWdc Jasper County Solar Project in Indiana.
Together, Zelestra and Meta have signed PPAs for roughly 1.4 GWdc of solar output across eight US projects, with a target operational date of 2028.
Phil North, Zelestra’s US CEO, commented that the partnership continues to turn ambition into delivery. He said that within a few months, the companies have brought Jasper County online, started construction on Skull Creek and Reclamation, and added Palmera to the portfolio. He added that they are accelerating the delivery of new energy infrastructure that supports Meta’s decarbonisation goals while providing long-term economic value in local communities.
According to Texas electric company Chariot Energy, a solar farm is a large collection of photovoltaic solar panels that absorb sunlight, convert it into electricity, and send it to power grids for distribution. There are two types: utility-scale and community. Utility-scale solar farms occupy large areas with huge solar panels, collecting energy and distributing it to high-voltage power lines connected to homes and businesses. Community solar farms typically produce about 5 MW of power for local residential and commercial needs.
In addition to solar farms, Meta has also made deals to start construction on multiple data centres across the United States.
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Lodestone Energy, Auckland-based New Zealand solar generation and retail company  and Waipukurau-based Centralines are planning to begin construction of Hawke’s Bay’s first utility-scale solar farm this spring. Centralines is a consumer-owned electricity lines business serving Central Hawke’s Bay, while Lodestone Energy develops large-scale solar farms across New Zealand. The $50 million project will be located on the Ruataniwha Plains in Central Hawke’s Bay. The project will have 31.5 MW (DC) of installed capacity with 49,000 solar panels and generates 50 GWh annually.It is expected to supply power to about 7,000 homes while it starts operations in late summer 2027. Electricity will feed directly into the Centralines network also supporting local generation and regional grid efficiency. Trina Solar has supplied 49,000 high-efficiency 640 W panels which have arrived in Napier for installation.

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I’ve tested solar power at home for years – 12 myths you shouldn’t fall for in 2026  ZDNET
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The consortium formed by Maco Construct (leader), Fair Play Șerban, Altige Impex, Veltol Holding, and Suntech Building has won a tender organized by Timișoara International Airport “Traian Vuia” for the design and construction of a photovoltaic park with an installed capacity of 7 MW.
The project, valued at RON 34.98 million, is financed through European funds. The sum is also below the initial estimates of RON 43.67 million, according to local news outlet Ziua de Vest.
Aside from the winners, the tender procedure was also attended by CAS Office Arhitect (leader), Filkab Solar and Morningstar Consulting, and, respectively, Corner Deposit (leader), Solar Eco Systems, Emsens Prod, and Ecoinstal Urban. 
Once complete, the installation will have sufficient capacity to cover an important part of the airport’s electricity needs and to contribute to reducing the carbon footprint of the airport infrastructure.
The works will be completed within 12 months from the date of contract award. The photovoltaic park will cover an area of ten hectares on land located south of the airport.
radu@romania-insider.com
(Photo source: Peter Lovas|Dreamstime.com)
The consortium formed by Maco Construct (leader), Fair Play Șerban, Altige Impex, Veltol Holding, and Suntech Building has won a tender organized by Timișoara International Airport “Traian Vuia” for the design and construction of a photovoltaic park with an installed capacity of 7 MW.
The project, valued at RON 34.98 million, is financed through European funds. The sum is also below the initial estimates of RON 43.67 million, according to local news outlet Ziua de Vest.
Aside from the winners, the tender procedure was also attended by CAS Office Arhitect (leader), Filkab Solar and Morningstar Consulting, and, respectively, Corner Deposit (leader), Solar Eco Systems, Emsens Prod, and Ecoinstal Urban. 
Once complete, the installation will have sufficient capacity to cover an important part of the airport’s electricity needs and to contribute to reducing the carbon footprint of the airport infrastructure.
The works will be completed within 12 months from the date of contract award. The photovoltaic park will cover an area of ten hectares on land located south of the airport.
radu@romania-insider.com
(Photo source: Peter Lovas|Dreamstime.com)
The consortium formed by Maco Construct (leader), Fair Play Șerban, Altige Impex, Veltol Holding, and Suntech Building has won a tender organized by Timișoara International Airport “Traian Vuia” for the design and construction of a photovoltaic park with an installed capacity of 7 MW.
The project, valued at RON 34.98 million, is financed through European funds. The sum is also below the initial estimates of RON 43.67 million, according to local news outlet Ziua de Vest.
Aside from the winners, the tender procedure was also attended by CAS Office Arhitect (leader), Filkab Solar and Morningstar Consulting, and, respectively, Corner Deposit (leader), Solar Eco Systems, Emsens Prod, and Ecoinstal Urban. 
Once complete, the installation will have sufficient capacity to cover an important part of the airport’s electricity needs and to contribute to reducing the carbon footprint of the airport infrastructure.
The works will be completed within 12 months from the date of contract award. The photovoltaic park will cover an area of ten hectares on land located south of the airport.
radu@romania-insider.com
(Photo source: Peter Lovas|Dreamstime.com)
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India’s rooftop solar sector is finally showing signs of catching up with the country’s utility-scale success story. Long constrained by high upfront costs, financing barriers and administrative hurdles, the residential segment has gained significant momentum since the launch of the government of India’s rooftop solar initiative PM Surya Ghar: Muft Bijli Yojana (PMSGY) in 2024. 
In early 2026, India’s total solar capacity surpassed 150GW, but one of the fastest-growing segments is now found on household rooftops. Under the PMSGY more than 3.3 million rooftop solar systems have been installed, adding over 12GW of capacity.
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According to analyst firms Institute for Energy Economics and Financial Analysis (IEEFA) and JMK Research, India deployed nearly 4.9GW of residential rooftop solar capacity in H1 of 2025, equivalent to almost 45% of the nation’s total installed residential rooftop solar base, driven by the PMSGY.
According to the Ministry of New and Renewable Energy (MNRE), monthly rooftop installations have surged from a mere 7,000 before the scheme’s introduction to over 300,000, while the time taken to add a hundred thousand beneficiary households has fallen from 118 days to fewer than eight.  
More than four million households have already benefited from the programme, with over 6.5 million applications currently in the pipeline and government projections targeting 7.5 million households by the end of 2026. 
To understand what is driving this rapid shift— and whether the momentum can be sustained—PV Tech Premium speaks with Gaurav Upadhyay, energy finance specialist for India sustainable finance in South Asia at IEEFA, about the evolution of India’s rooftop solar market, the role of PMSGY, financing dynamics and the challenges that still lie ahead. 
Historically, India has prioritised utility-scale solar for its speed in delivering capacity via competitive auctions and attracting large-scale investment. Rooftop solar has lagged due to fragmentation and the complexity of reaching millions of consumers facing varied financial and administrative barriers. 
Upadhyay highlights the accelerating pace of residential solar expansion, arguing that, “today, the economics and policy environment are much more favourable.”
“Government subsidies have reduced upfront costs, awareness has increased substantially, and installation procedures have become simpler. Rising electricity tariffs are also making self-generation increasingly attractive for households and businesses. As a result, rooftop solar is moving from an early-adopter technology to a mainstream consumer product.” 
The government’s main target under PMSGY is to install rooftop solar systems on ten million households and achieve approximately 30GW of operational residential rooftop solar capacity by FY2027. The programme has an approved outlay of INR750.21 billion (US$7.8 billion), making it one of the largest residential solar programmes globally. 
According to Upadhyay, rooftop solar plays a unique role in India’s clean energy transition because it complements utility-scale renewable energy.  
“Unlike large solar parks, rooftop systems require no additional land acquisition and generate electricity close to where it is consumed. This helps reduce transmission losses, lowers peak demand, and improves grid resilience. As India pursues its target of 500GW of non-fossil fuel capacity by 2030, distributed solar can become a critical pillar of the energy transition,” he says. 
PMSGY has emerged as a catalyst for India’s rooftop solar market. Earlier, adoption was largely confined to commercial and industrial (C&I) users, with households deterred by high upfront costs and complex approvals.
The scheme has since unlocked strong consumer demand, with 5.8 million applications received and 1.6 million installations completed by July 2025. Meanwhile subsidy disbursements exceeded INR 92.8 billion.
Rooftop solar economics have strengthened, with subsidies of up to INR78,000 under PMSGY reducing upfront costs. Payback periods are typically four to six years in higher-tariff states, but they can be longer elsewhere, while systems deliver 20–25 years of output. Savings are highest for high-consumption households, which offset more grid power and achieve faster returns.
“PMSGY has created confidence across the value chain. The national portal, direct benefit transfer (DBT) mechanism and simplified procedures have reduced many of the friction points that previously discouraged consumers,” says Upadhyay.  
However, IEEFA’s research shows that strong demand under PMSGY has not consistently translated into installations. By July 2025, the scheme had received around 5.8 million applications, but only about 22.7% had been completed. Additionally, performance varies sharply by state, with Gujarat and Kerala seeing more than 65% of their project applications approved—a figure IEEFA calls ‘installation to application ratio’—, while Rajasthan and Uttar Pradesh posted ratios of 21.8% and 14.8%, respectively.
Upadhyay attributes this disparity to “stronger implementation frameworks, proactive power distribution company (DISCOM) engagement and higher consumer awareness, while several other states continue to lag.” 
Looking ahead, IEEFA highlights the need for greater regulatory consistency across net metering rules, approval timelines and DISCOM practices, alongside stronger financing ecosystems, improved consumer awareness, expanded installer training and more efficient grievance redressal. 
Earlier, many DISCOMs had been cautious about rooftop solar as it displaces high-value electricity sales, particularly from commercial and industrial consumers. These segments typically pay tariffs above the cost of supply, cross-subsidising residential and agricultural users. 
Upadhyay emphasises that with the increased adoption of rooftop solar, “DISCOMs risk losing some of their most profitable customers, which can further strain their financial position. This concern is particularly relevant given the fragile fiscal condition of many state-owned DISCOMs.” 
However, the rooftop solar–DISCOM relationship is gradually evolving. “Distributed solar can reduce technical losses, ease peak demand, defer network upgrades and improve grid resilience by generating closer to load centres,” says Upadhyay “Under PMSGY, it can also moderate residential demand growth and limit the need for new capacity additions.”
While PMSGY has driven momentum, financing constraints, particularly for low- and middle-income households, continue to pose the biggest barrier, Upadhyay notes. 
“While public sector banks offer lower rates but slower approvals, non-banking financial companies (NBFCs) provide faster credit at higher costs,” says the analyst. “Consumer awareness also remains uneven, especially in smaller cities and rural areas, where many households are still unfamiliar with financing options, system performance and installation processes.”
Another challenge is scaling the installer ecosystem to match rapid demand, including quality assurance and after-sales service. Persistent delays in net metering, inspections and commissioning, along with regulatory inconsistencies, continue to create uncertainty, while supply chain constraints and domestic manufacturing requirements can also impact timelines and equipment availability. 
He argues that, looking ahead, “grid integration and regulatory innovation will be key to scaling distributed solar. This will require smarter distribution networks, digital monitoring and storage, alongside expanded models such as virtual and group net metering, community solar and RESCO frameworks to reach apartments, tenants and households without suitable rooftops. Addressing these gaps will be critical to converting strong demand into sustained deployment.” 
The next phase of growth will require policy innovation beyond conventional rooftop models. Virtual and group net metering can help apartment residents, tenants, and small businesses access solar from off-site generation, expanding the addressable market and already showing promise in states such as Maharashtra. 
By 2030, rooftop solar is set to play a key role in India’s distributed energy mix alongside utility-scale projects. It offers distinct advantages, including lower bills, reduced transmission losses, improved energy security, and greater consumer empowerment. 
“The success of the next phase will depend less on subsidies and more on execution,” concludes Upadhyay. “Faster approvals, stronger financing ecosystems, improved installer quality, supportive state policies, and deeper integration with battery storage and smart-grid technologies will determine whether rooftop solar achieves its full potential. If these elements come together, rooftop solar could become one of the most visible and inclusive aspects of India’s clean energy transition.” 

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‘We welcome the court’s decision, which provides further certainty for the Woolley Solar Farm project and confirms the robustness of the planning process,’ said Mark Hogan, founder of BOOM Power.
June 12, 2026
The UK High Court has dismissed a legal challenge raised by a local resident against independent power producer (IPP) BOOM Power, which had received planning permission to build the 29.7MW Woolley solar PV project in Wakefield, West Yorkshire.
The resident, identified in court documents as “Lang J.”, argued that the process by which the local planning authority (LPA) had gone about awarding planning permission in August 2025—namely, disagreeing with an assessment made by its design and conservation officer that local views would be “spoiled” by the installation of solar panels—was flawed.
However, Sir Tim Kerr, a judge of the High Court, wrote in his conclusion, dated 29 May and published by BOOM Power this week, that Lang’s arguments “lack merit”.
“In my judgment, on close scrutiny, these grounds lack merit,” wrote Kerr. “As the application and the process of examining it evolved, different judgments and opinions were formed and held by different parties at various times. That is both normal and lawful; indeed, it is a mark of a healthy consultation process and consideration by the LPA of its fruits.”
Related:Gülermak Renewables, ElectroRoute ink 50MW CfD-backed PPA
“We welcome the court’s decision, which provides further certainty for the Woolley Solar Farm project and confirms the robustness of the planning process,” added Mark Hogan, founder of BOOM Power. “This is an important scheme that will contribute to the UK’s renewable energy capacity and net zero ambitions, following a thorough and properly tested planning determination.”
BOOM Power said that it expects to complete construction work at the project in “around nine months”.
The victory for BOOM Power follows years of uncertainty regarding the project, for which the IPP first sought planning permission in December 2023. The site is on green belt land to the east of the M1 Motorway, across from the Bretton Hall Registered Park and Garden, a Grade II listed building; Kerr described this application to build a solar project on such a site as “ambitious” at the time.
However, the publication of a new National Planning Policy Framework (NPPF) by the government in December 2024 aimed to remove barriers to the deployment of renewable energy projects by urging planning authorities to give “significant weight” to the energy transition benefits associated with new renewable energy installations.
The framework also introduced the so-called ‘grey belt’, areas of land once described as green belts that are considered poor-quality land, a category into which the land for the Woolley project fits.
Related:Earlier commitment, not just engagement: Solar developers’ response to supply chain constraints
The planning process also noted that there would likely be “no significant adverse impact” of the project’s deployment on this site. As a result, the planning committee granted planning permission to the project on 7 August 2025, agreeing with an assessment made by planning officers that “whilst there would be a change to the character of the field from agricultural to developed as a solar farm, the impact would be localised and the negative impact on the landscape is considered to be limited.”
It was this 7 August decision to which Lang objected, saying that the grey belt designation was “a political sleight of hand” that “seeks to bypass long-standing protections for our countryside”. However, the same documents suggest that he was not confident in the success of his objection, noting that “he anticipated that the development would be allowed”. 
Similar appeals have seen grey belt projects go ahead, with objections the like of the one to BOOM's project doing little other than to slow development and add expense.
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Industry bodies challenge ALMM List-II rule, citing high domestic solar-cell prices, inadequate capacity, and rising project costs.
June 12, 2026. By EI News Network
Solar manufacturers and project developers have approached the Karnataka High Court challenging the Ministry of New and Renewable Energy's (MNRE) mandatory domestic solar-cell sourcing requirement, arguing that the policy could significantly increase project costs and disrupt project execution.

The writ petition, led by the Karnataka Renewable Energy Systems Manufacturers Association (KRESMA), seeks to quash or defer the Ministry of New and Renewable Energy's (MNRE) Approved List of Models and Manufacturers (ALMM) List-II mandate, which came into force on June 1, 2026. The rule requires most solar projects commissioned after that date to procure photovoltaic cells only from manufacturers approved under the government's domestic supplier list.
Industry representatives contend that the mandate has been implemented despite a substantial gap between domestic manufacturing capacity and market demand. According to the petitioners, domestically manufactured solar cells listed under ALMM List-II are priced at around INR 13 per watt, compared with imported cells available at roughly INR 5 per watt. They argue that the price differential is placing an excessive financial burden on developers and could slow the pace of solar deployment.
The petition also claims that India's current approved domestic cell manufacturing capacity is insufficient to meet the requirements of the rapidly growing solar sector. Developers have urged the court to suspend enforcement of the mandate until adequate domestic capacity becomes available and prices become more competitive.
The legal challenge comes after the MNRE declined industry requests for a blanket extension of the June 1 implementation deadline. The ministry had earlier stated that the timeline would remain unchanged following consultations with stakeholders, although it introduced a mechanism allowing project-specific exemptions in cases where substantial investments had already been committed before the mandate took effect.
In a separate move aimed at supporting rooftop solar adoption, the MNRE on June 9 announced a limited relaxation of the ALMM List-II requirement. Residential rooftop solar projects installed under the PM Surya Ghar programme without central financial assistance will remain exempt from the domestic-cell sourcing rule until March 31, 2027.
The ALMM List-II mandate forms part of the government's broader strategy to strengthen domestic solar manufacturing, reduce reliance on imports, and build a self-reliant clean energy supply chain. However, industry groups maintain that the transition should be aligned with manufacturing readiness to avoid cost escalations and project delays.
As of June 12, the Karnataka High Court had not issued any interim order or stay on the implementation of the mandate, and the matter remains under judicial consideration.

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El Salvador Secures USD 9.6 Million Kuwait Loan to Develop San Matías Solar Power Plant, Strengthening Renewable Energy Capacity  SolarQuarter
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A solar panel installed this spring will likely still be generating electricity when today’s kindergartners graduate from college. Panels are built to last 25 to 30 years, and the earliest rooftop and utility installations from the 2000s solar boom are now reaching the end of that run.
That first wave of end-of-life panels is the leading edge of a much larger, ongoing challenge, to recover and reuse the materials that convert the sun’s energy into electricity. Nearly everything inside those panels can be recovered and sold back into the supply chain. Today, very little of it is. The International Renewable Energy Agency (IRENA) projects that global solar panel waste could reach 78 million tons by 2050.
The U.S. Environmental Protection Agency expects the United States to generate as much as one million tons of panel waste by 2030 and up to 10 million tons by 2050, the second-largest national total in the world. IRENA estimated in 2016 that the raw materials reclaimable from end-of-life panels will be worth about $450 million globally by 2030 — enough to build some 60 million new panels — and will grow to $15 billion and roughly 2 billion panels’ worth of material by 2050.
Strip a crystalline-silicon module, the type that dominates the solar panel market, down to its components and most of what you find is glass. A panel is roughly 75 percent glass by weight, framed in aluminum and built with copper wiring, polymer layers, a plastic backsheet, the silicon cells themselves, and a junction box. The greatest value sits in the small fraction of these materials: silver, copper, high-purity silicon, plus tin and antimony, and in thin-film panels, tellurium and indium.
Older panels also carry trace lead in their solder, which the reason some are classified as hazardous waste when they break down, as Inside Climate News has reported. Thin-film modules from First Solar and a few others use cadmium telluride, which is stable in the panel but adds its own end-of-life handling requirements. Thin-film remains a small share of the market, under 5 percent globally, so crystalline silicon is the focus of most recycling efforts.
Recovering these materials matters well beyond saving landfill space. Recycled aluminum takes roughly 95 percent less energy to produce than aluminum smelted from ore, and recovered silver and silicon reduce the mining and refining that go into every new panel.
Several of those metals also sit on the U.S. critical-minerals list. The EPA notes that panels can contain aluminum, tin, tellurium, and antimony, with gallium and indium in some thin-film modules, much of which the country currently imports. Recovering them at home converts a disposal headache into a small but genuine piece of supply-chain resilience, and it does so close to where new panels are increasingly being manufactured.
The first obstacle is economics. Sending a panel to a landfill costs about $1 to $5; recycling the same panel runs roughly $15 to $45, according to National Renewable Energy Laboratory figures cited by Chemical & Engineering News (C&EN). Arizona State University researcher Meng Tao, who studies PV recycling, has put the gap plainly to MIT Climate: recycling a panel costs around $20 and yields about $10 to $12 in recovered materials. For a single rooftop system, the math today rarely favors recycling without subsidies.
The technical challenge compounds the financial one. The EPA describes recycling as three escalating steps: remove the aluminum frame and junction box; separate the glass from the silicon wafer using thermal, mechanical, or chemical methods; then purify the silver, silicon, copper, and other metals. Removing the frame is straightforward, and a lot of recycling stops there and the rest gets shredded and sold as low-value glass cullet, C&EN notes. Teasing the glass from the cells and then separating the silver and silicon is far harder, and no single commercial process yet recovers all of it cleanly.
Consequently, the United States currently recycles only about 10 percent of decommissioned panels, while the European Union recovers around 85 percent, according to Public Citizen. The encouraging counter-trend is the rapidly decreasing cost of panel recycling: one industry analysis from Solar Power World reports that the true-recycling costs declined by 42 percent over the past three years, and the most advanced facilities now recover up to 95 percent of a panel’s value.
Reuse offers a partial release valve. Panels that fail early or get swapped out during a system upgrade often still work, and a growing secondhand market resells them at a discount for off-grid, agricultural, and overseas projects. Keeping a working panel in service, or passing it to someone who will, sidesteps the cost-and-complexity problem entirely, which is why reuse remains a bigger share of outcomes compared to recycling.
Public investment is starting to bend the curve, too. The U.S. Department of Energy has funded a slate of PV recycling projects aimed at closing the gap, even as the National Renewable Energy Laboratory has projected that, without faster action, the country would still recycle only about a tenth of its panels by mid-century. The first matters because the second is not inevitable.
A recent market map from MarketsandMarkets lists more than a dozen leading players in solar panel recycling, and reading it closely shows how young and mixed the field still is. It blends three kinds of company: panel manufacturers with their own take-back programs, dedicated PV recyclers, and global waste-management firms moving into the category.
First Solar anchors the first group. The U.S. thin-film manufacturer has run a closed-loop process since 2005, recovering more than 90 percent of each module’s materials in its panels, including the semiconductor itself, for reuse.
Among dedicated recyclers, SOLARCYCLE opened a high-throughput facility in Georgia in 2026 that recovers about 96 percent of a panel’s value — silver, copper, aluminum, and glass — and is scaling toward processing up to 5 gigawatts of panels a year, Solar Washington reports. We Recycle Solar runs a utility-scale plant in Yuma, Arizona, and plans to roughly quadruple its capacity by 2028. In Europe, ROSI, a French company, uses a thermal-and-chemical process to recover high-purity silicon and silver — the toughest materials to reclaim — and recently raised more than $20 million to build a 10,000-ton-per-year facility in Spain. Veolia and Germany’s Reiling round out the European side as larger waste and glass recyclers expanding into PV.
The arrival of so many well-capitalized firms signals that the waste stream is finally large enough to support an industry. The catch is that most of this capacity sits in Europe or at the utility scale, where project owners can absorb the cost, which leaves rooftop owners with fewer easy options for now.
Solar Recycling Companies in 2026
A note on pricing: most of these companies serve utilities, installers, and manufacturers and quote by project, so public per-panel rates are rare.
Much of the distance between 10 percent and 85 percent comes down to rules. The EU’s Waste Electrical and Electronic Equipment (WEEE) directive requires panel producers to finance the collection and recycling of every panel they sell in Europe. The United States has no equivalent federal framework.
That is beginning to change, slowly. In October 2023, the EPA announced it would add retired solar panels to its “universal waste” rules, a streamlined category for widely generated hazardous materials such as batteries and pesticides. The proposed rule was originally due in 2025; the agency’s current timeline pushed the proposal to February 2026 and a final rule to August 2027. Until it takes effect, panels can be landfilled as ordinary trash in most states.
A handful of states have moved on their own. Washington created a manufacturer-funded stewardship program that requires producers to take back panels at no cost to the owner, and California classifies end-of-life panels as universal waste requiring specialized handling, as Earth911 has documented. Texas and North Carolina have begun restricting panel disposal as well. For now, what happens to a retired panel depends heavily on where it was installed.
Federal law already reaches panels through the Resource Conservation and Recovery Act. Whoever discards one is technically responsible for determining whether it qualifies as hazardous waste — a determination that hinges on whether metals such as lead leach above regulatory limits in a standardized test. Many intact silicon panels pass and are not hazardous; some, especially older modules with lead-based solder, do not.
For a homeowner, the EPA’s guidance is more straightforward in the meantime: contact your installer or state environmental agency rather than guess.
Whether you own a single rooftop array or manage a portfolio of sites, end-of-life options are improving. A few practical steps:
For homeowners and individuals
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The materials inside a solar panel were mined, refined, and assembled at a real environmental cost. Recovering them closes the loop on an energy source designed to be clean from start to finish, and the infrastructure, companies, and rules to do it are finally catching up to the wave.
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TGS Prediktor Delivers SCADA Solution for Scatec’s 225 MWAC Grootfontein Solar Project  energynews.pro
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LONGi, a China-based green energy technology company, has announced that multiple cell and module efficiency achievements were included in the 68th Solar Cell Efficiency Tables. The tables were released by Professor Martin Green’s team at the University of New South Wales in Australia and feature only independently certified highest efficiency records. The listing included LONGi’s single-crystalline silicon cell efficiencies of 27.8% and 28.13%, with 28.13% identified as a world record. LONGi’s two-terminal crystalline silicon-perovskite tandem cell with 35.2% efficiency was also featured. Under conditions nearer to industrial-scale dimensions, the company recorded 34.3% efficiency at 261 cm² and 32.2% at 274 cm². At the module level, its 26.4% crystalline silicon module efficiency was described as the highest record for crystalline silicon modules. The report also included LONGi’s independently certified tandem module efficiencies of 31.4% and 29.4%. The tables require independent certification and standardized test conditions for comparability across different technology routes.

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Researchers Achieve Record 20%+ Efficiency in Flexible Kesterite-Perovskite Tandem Solar Cells  AZoCleantech
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Chinese PV manufacturer Trinasolar has launched its Vertex N Shield photovoltaic module in North America. It is designed primarily for commercial and industrial (C&I) and utility-scale solar projects.
The module is designed for performance in a climates with increasingly severe hail storms and shifting wind loads that impact project insurance premiums and long-term asset bankability. 
The Shield line is its equipped with a dual-glass assembly featuring reinforced glass with a surface compression stress exceeding 69 MPa. The design delivers an impact energy resistance that is 2.5 times higher than conventional PV hardware.
The mechanical upgrades allow the modules to withstand severe hail impacts, passing certifications for direct strikes from 55 mm (2.1-inch) diameter hailstones at terminal velocities of 33.9 m/s, as well as up to 75 mm (3-inch) hailstones hitting the glass surface at a 45-degree angle.
Beyond hail impact resistance, the structural frame layout has been designed to handle complex wind and snow loading conditions across diversified terrain profiles: 
The electrical characteristics of the Vertex N Shield line mirror the performance metrics of Trinasolar’s existing medium-format n-type portfolio, utilizing a 210R rectangular cell structure across a 132-cell layout. 
Operating on an n-type tunnel oxide passivated contact (TOPCon) platform, the flagship module features a peak power output of 620 W with a maximum module efficiency rating of 23.0%. The lower temperature coefficient of -0.29%/°C ensures sustained performance in elevated ambient thermal environments, while its low-voltage design supports longer string configurations to trim down overall balance of system (BOS) capital costs. 
Cell Platform Type 
N-type i-TOPCon Monocrystalline (210 mm) 
Module Format Layout 
132 half-cut cells 
Dimensions 
2382 mm × 1134 mm × 30 mm 
Weight 
39.7 kg (87.5 lbs) 
Maximum Power (Pmax) 
620 W 
Module Efficiency 
23.0% 
Open Circuit Voltage (Voc) 
49.6 V 
Short Circuit Current (Isc) 
15.91 A 
Temperature Coefficient (Pmax) 
-0.29% / °C 
Environmental degradation test sequences from Kiwa PVEL indicate long-term stability of the module under severe field operations. The line has secured safety and longevity certifications covering potential-induced degradation (PID), light-induced degradation (LID), and light- and elevated temperature-induced degradation (LeTID), along with accelerated environmental exposure testing for salt mist, ammonia, and high-density dust. 
The modules carry a UL 61730 Fire Type 30 designation with comprehensive Class A performance metrics across standard fire evaluations.  
Trina backs the module with a 30-year linear performance guarantee, limiting the first-year power degradation to 1.0% and enforcing an annual drop-off ceiling of 0.4% from years 2 through 30. 

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Indian PV manufacturer Bluebird Solar has launched a new range of G12R n-type TOPCon bifacial PV modules targeting utility-scale, commercial and industrial (C&I), and rooftop solar applications.
The new module series offers power outputs of up to 630 Wp and module efficiencies of up to 23.32%, enabling higher energy generation and improving project economics.
The modules are based on n-type TOPCon cell technology and G12R rectangular wafers, enabling integration of a higher number of cells within a compact design to increase power density and optimize space utilization.
The bifacial glass-to-glass design generates additional power from the rear side through reflected sunlight, improving overall plant performance and long-term energy output. The module features 132 half-cut cells with 16BB technology and is backed by a 12-year product warranty and 30-year power output warranty.
“Our new G12R module has been engineered to meet the evolving needs of modern solar projects by delivering higher energy yield, lower degradation, and better project economics,” said Akshay Mittal, director, Bluebird Solar.
“As the industry moves rapidly toward high-efficiency n-type solutions, our focus remains on providing advanced modules that offer superior performance, reliability, and long-term value for our customers,” added Rohit Tikku, CEO, Bluebird Solar.
Bluebird Solar currently operates a fully automated 2.5 GW PV module manufacturing facility in Greater Noida, Uttar Pradesh, producing high-efficiency mono PERC and n-type TOPCon solar modules for residential, commercial, industrial, and utility-scale applications.
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An Adelaide landmark building first licensed as a hotel in 1839 and once known as the Electric Light Hotel, has employed renewable energy systems into its latest refurbishment as a commercial office space.
Designed and installed by Adelaide-based clean energy company MyEnergy Engineering the commercial 29.04 kW rooftop solar system features Trina solar panels mounted with a Schletter roof mount system, chosen to protect the heritage terracotta tile rooftop structure.
The panels are paired with a Deye 25 kW three-phase high-voltage (HV) Battery Hybrid Inverter to manage energy generation and storage, supported by 40.96 kWh of Pylontech Force H3 batteries.
Located in the Adelaide CBD, and after years of closure, the now-named Producers Hotel is being redeveloped to restore its heritage features and create a modern, energy efficient commercial space within.
MyEnergy was engaged to design and install a system that has flexibility to scale as demand at the site grows and also to maintain supply in the case of a power blackout.

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Enter a search term into the form to search the site; to search a specific phrase please include that phrase within quotation marks (eg “Principality Event”)
12th June 2026, 12:35 pm By Sophie Archer
Solar panels generating enough electricity to power more than 50 matchdays have been turned on at Principality Stadium in Cardiff. The switch-on marks a key step in the Welsh Rugby Union’s decarbonisation plans as it prepares to unveil its first sustainability strategy later this year. 

Over 3,250 solar panels, have been fitted to the Stadium’s iconic roof by EvoEnergy, the UK’s leading renewable company, making it the largest such installation at any sports stadium in the UK. 
The panels will significantly decarbonise Principality Stadium’s operations through the production of clean energy, generating an expected 1.25 million kilowatt-hours of electricity each a year ─ enough to host a packed matchday at the home of Welsh rugby every day for seven weeks.  
The panels are expected to reduce Principality Stadium’s carbon output by 219,791kg every single year, providing a substantial source of low-cost energy for the Welsh Rugby Union. 
The solar installation is part of a wider package of sustainability measures aimed at decarbonising Principality Stadium’s operations. The WRU is now developing a full-fledged sustainability strategy, which will draw on all of its current and future efforts to drive decarbonisation and broader societal change across the whole of Welsh rugby.  
Gavin Marshall, WRU Chief Financial and Operating Officer said, “This marks a hugely exciting milestone, not just for Principality Stadium, but for the future of Welsh rugby. As one of the most iconic sporting venues in the world, it’s right that we harness its scale and influence to drive positive change, benefiting our game, our fans and the wider community.  
“While matchdays here will always be ignited by a sea of red jerseys, we’re proud that they will now be powered by clean green energy. Investing in innovative, sustainable energy solutions like solar is vital if we are to future-proof the stadium and play our part in creating a greener future.  
“We’re not only reducing our carbon footprint but also strengthening the financial sustainability of the Union through the money we will save, creating long-term value that can be reinvested into Welsh rugby at every level. 
“Through the publication of our sustainability strategy later this year, we’ll set out how initiatives like today’s contribute to a bold, practical plan to make Welsh rugby greener and more resilient for generations to come.”  
The solar installation sit alongside other measures, such as the introduction of a well water abstraction system (which ensures clean drinking water is not wasted on cleaning or watering needs), rain-water harvesting, installation of LED lighting throughout the stadium. There is also a commitment to sustainable food procurement and to working with local charities to ensure surplus food gets distributed within vulnerable communities  
The full sustainability strategy is set to be published later this year and will ensure sustainable practices sits at the heart of the WRU’s five-year One Wales corporate strategy. 
Darren Crossman, WRU Head of Facilities and Safety and Sustainability, adds, “As custodians of this iconic stadium, we have a responsibility to lead by example, and this solar installation is a significant technical and operational step forward. 
“This project is about more than generating renewable energy, it’s about embedding sustainability into the way the stadium operates day-to-day, reducing our environmental impact and creating a more efficient, resilient venue for the future. 
We’re proud to bring this expertise to life at Principality Stadium and marking this first step in shaping a future sustainability strategy for Welsh rugby. 
Diala Isid, Senior Renewable Energy Consultant at EvoEnergy, said, “We’re proud to have partnered with the Welsh Rugby Union to deliver a landmark solar PV system, reflecting a shared commitment to clean energy and a more sustainable future.”  

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The Roanoke County School Board approved a $1.5 million rooftop solar energy project for its new Career and Technology Center on Thursday, with the goal of saving on operating costs and creating new educational opportunities for students.
Roanoke County Public Schools’ Career and Technology Center is seen under construction in a video posted in February. The building is expected to open in early 2027.
Alexia Partouche 
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alexia.partouche@roanoke.com

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Roanoke city and county now join Montgomery County, Salem and dozens of other locations in Virginia in being part of Dolly Parton’s program.
Roanoke County Public Schools’ Career and Technology Center is seen under construction in a video posted in February. The building is expected to open in early 2027.
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Built on Trina’s 210mm n-type TOPCon advanced technology platform, Vertex N Shield combines high-energy yield with improved mechanical durability, aiming to increase long-term reliability and commercial and industrial (C&I) solar project bankability. 
The new Vertex N Shield has been designed to directly address the challenge of extreme weather events, which are among the fastest-growing sources of risk for solar asset owners, with a comprehensive suite of mechanical and environmental certifications as well as safeguards against additional weather events like snow and fire:
Severe Hail Resistance: Certified to withstand direct hail impact from 55 mm diameter hailstones at 33.9 m/s, and up to 75 mm hailstones at a 45-degree angle.
Strong Wind Protection: Engineered to handle extreme static mechanical loads of +7,000/-5,000Pa, suitable for high-wind and hurricane-prone regions.
Heavy Snow Loads: Rated for uneven snow loads up to +6,600Pa, equivalent to approximately 7.2 feet of snow accumulation.
Superior Fire Rating: Certified to UL 61730 Fire Type 30 with Class A performance across all UL fire tests, exceeding current industry standards.
Along with a 30-year power guarantee and an industry-low annual degradation rate of just 0.4 percent, the Vertex N Shield has also passed salt mist, ammonia, dust, PID, LID, and LeTID certifications, increasing its resilience across coastal, agricultural, arid, and high-humidity environments. RETC’s 2025 PV Module Index recognised the Vertex N Shield as the “Overall Highest Achiever” in 2025.
On June 17, John Dallapiazza, Director of US Utility Module Sales with Trinasolar US, will join the PV ModuleTech USA panel discussion, “Maximising PV Performance at the Component Selection and Build Stage”, to talk about the benefits of the hail-hardened Shield modules and the real costs to solar PV arrays caused by weather-related damage.
“The Shield module’s extreme mechanical strength meets severe loading requirements and delivers excellent resistance to extreme weather and environmental risks” said Eric Cao, Vice President of Trinasolar North American PV Business. “Trinasolar’s proven track record as a BNEF Tier 1 manufacturer and the Vertex N Shield’s durability reinforce investor confidence and maximise long-term returns for stakeholders while reducing insurance costs and payout risks.”
The Vertex N Shield module is available immediately for North American C&I & Utility-scale projects.
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From pv magazine India
India has more than 102 GW of deployable floating solar PV potential, according to a new report from the National Institute of Solar Energy (NISE). The assessment increases the country’s total assessed solar energy potential from ground-mounted and floating PV installations to 3,445 GW.
A previous NISE report estimated India’s deployable ground-mounted solar PV potential at 3,343 GW (DC).
The floating solar assessment was unveiled by Union Minister for New and Renewable Energy and Consumer Affairs Pralhad Venkatesh Joshi, who said the Ministry of New and Renewable Energy (MNRE) is preparing a dedicated scheme to accelerate floating solar deployment across the country.
NISE applied a series of screening criteria to identify suitable water bodies for floating solar development. The assessment considered hydro-lake water bodies with a minimum area of 10 hectares, excluding smaller sites deemed unsuitable for utility-scale projects. Additional criteria included year-round water availability, water depths of 3 m to 30 m, minimum global horizontal irradiation (GHI) of 4.5 kWh/m²/day, and locations within 10 km of both road networks and electrical substations.
For the analysis, NISE assumed the use of 545 W solar modules with 21% efficiency installed at a 5-degree tilt angle. Under these assumptions, the institute estimated that 0.019 km² of water surface area is required to deploy 1 MW of floating solar capacity.
To reduce ecological impacts and preserve competing uses such as fisheries, the assessment limits floating solar installations to a maximum of 20% of the surface area of each eligible water body.
Of the 10,725.99 km² of mapped water body area across India, NISE identified 4,546.01 km² as suitable for floating solar development. Applying the 20% utilization cap at the state level yields an effective deployment area of 1,946.24 km², corresponding to a national floating solar potential of 102.18 GW.
Maharashtra has the highest assessed floating solar potential at 16.28 GW, followed by Madhya Pradesh (14.89 GW), Karnataka (13.69 GW), Odisha (12.81 GW), and Telangana (10.72 GW).
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The U.S. government has added several prominent energy storage and solar companies to its list of designated “Chinese military companies,” meaning its Department of Defense will be banned from doing business with them and purchasing their products from 2027.
The list, updated on June 9 by U.S. Deputy Secretary of Defense Stephen A. Steinberg, includes well-known Chinese solar and energy storage companies such as CATL, Three Gorges, EVE Energy, Huawei, BYD, JA Solar, and Trina Solar.
The organizations listed are banned under US law from doing business with the US Defense Department due to their perceived links to the Chinese state. The list includes Chinese companies engaged in providing commercial services, manufacturing, exporting, or operating in the United States – either directly or indirectly.
Others listed in the updated list include retailer Alibaba, China Electronics Corp., and China General Nuclear Power Corp. Many companies listed are operating in the energy, technology, security, and aerospace sectors.
This move comes as part of the increasing US crackdown on trading with China.
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One of China’s largest PV manufacturers, JA Solar, has announced a global rebranding and change of name to JA.
The company said the move reflected the company’s evolution from PV module manufacturer to a “fully integrated green energy ecosystem partner”, spanning power generation, energy storage and optimisation.
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Under the rebrand, JA said the company would be structured beneath its “masterbrand around four key business groups: JA SOLAR (PV), JA ESS (energy storage solutions), JA GREEN (smart energy) and JA CAPITAL (financing).
Announcing the rebrand at an event in Shanghai last week, Liu Shuo, president of JA’s Brand and Marketing Centre, said: “The global energy transition is shifting from electricity price competition to a value-driven phase deeply integrated into specific scenarios. Drawing on 21 years of solar expertise and our mission to ‘develop solar power to benefit the planet’, JA will deepen the green energy ecosystem to make green energy stable, accessible and affordable for every industry, advancing the transition together with global partners.”
From “exporting products” to “building global capabilities” and from “a Chinese brand going global” to “a truly global brand”, Liu Shuo said JA would deliver integrated green energy solutions, collaborating with partners across the industry to co-develop technologies and expand markets.
“Through reliable products, tailored system solutions, global professional services and consistent long-term value, JA will empower industries worldwide to build a more stable, greener and sustainable energy future,” he added.
As reported by PV Tech, last week’s SNEC expo in Shanghai heard executives from some of China’s leading PV manufacturers discuss how they plan to extricate their companies from the cycle of oversupply and negative profitability that has dogged the industry for the past two years. A key theme was the need to transition into broader integrated clean energy providers, embracing technologies such as energy storage and artificial intelligence alongside their core PV expertise.

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Almost all the economic value in a crystalline silicon solar module is concentrated in one material. Silver accounts for just 0.03% of a panel’s mass, but, according to data presented by Dr. Andreas Obst, head of recycling at Fraunhofer CSP, a German solar research institute, it can be worth more than the glass, aluminum and silicon combined.
A standard crystalline silicon solar module weighs approximately 11.6 kg. Obst said glass accounts for 67.5% of that weight but yields only around EUR 34 ($39) per module at current prices. The aluminum frame – 12.7% by weight – yields around EUR 229. The silicon cells, at 2.7% of module weight, generate roughly EUR 38. The silver contacts, representing just 0.03% of module mass, are worth approximately EUR 600 per module at the material prices cited by Obst.
“When you’re talking about recycling of solar modules, you should talk about silver recovery,” said Obst. “The silicon from the solar cells just accounts for roughly 2.7% of the weight of an individual module – it’s really not that much money which would come out of the solar cells itself.”
Modules installed during Europe’s subsidy-driven buildout in the late 2000s are approaching the end of their 20-year support periods. Drawing on German installation and subsidy data, Obst estimated that Germany alone could face approximately 600,000 metric tons (MT) of PV waste per year at the peak of that wave in the early 2030s.
A 2016 joint projection by the International Renewable Energy Agency (IRENA) and the IEA Photovoltaic Power Systems Programme (IEA-PVPS) put cumulative end-of-life PV volumes at between 1.7 million MT and 8 million MT globally by 2030.
Prof. Yansong Shen, director of the ARC Research Hub for Photovoltaic Reliability and Sustainability at the University of New South Wales, estimated that Australia alone would face approximately 1 million MT of cumulative end-of-life panels by 2035. In Australia, by Shen’s account, recycling infrastructure is nowhere near that scale, with current capacity largely focused on aluminum frames and glass. A credible national system, he said, could begin emerging within three to five years.
Silver value
Shen cited spot silver prices of around $68 to $69 per troy ounce at press time, up from roughly $20 two years earlier. Obst said part of that rise reflects growing PV industry demand and the absence of recycling infrastructure. He said the global PV industry consumed approximately 6,000 metric tons of silver in 2023, against world annual mine production of roughly 30,000 metric tons, citing data from the Silver Institute.
Specific silver consumption per unit of installed capacity has fallen from roughly 200 MT per gigawatt-peak in 2006 to under 30 MT per gigawatt-peak today, but total industry demand has risen with deployment volumes.
“Silver reserve is being used up in PV manufacturing sectors,” Shen told pv magazine. Without continued silver-thrifting, copper substitution, and large-scale recycling, he said, most currently known silver reserves could be consumed within 25 years.
Obst drew a comparison with the photographic industry, which at its peak consumed roughly 35% of global annual silver production but recovered more than 70% of what it used. “The PV industry is nowhere near that,” he said.
Silver in a PV module is not straightforwardly recoverable – it is finely dispersed through the cell metallization and encapsulated in the laminate. Recovering it requires either a hydrometallurgical or pyrometallurgical process, said Obst. “To recover the silver you need more advanced techniques. It’s not that easy to recover as for example the aluminium frame, which you can just separate mechanically.”
No commercial hydrometallurgical recyclers responded to requests for comment. Obst’s assessment, based on Fraunhofer CSP’s process development work, was that a dedicated hydrometallurgical line requires throughput of several thousand metric tons of solar cells per year to justify its capital cost – a view that could not be independently tested against commercial operators.
Mechanical separation
The most common approach in current commercial PV recycling facilities is mechanical separation. The method carries lower operating costs but Ko said it contaminates high-value material streams when it relies primarily on crushing and shredding.
“Once glass, silicon, metals, and polymers are reduced into mixed particles, contamination becomes a significant challenge regardless of the subsequent separation technology employed,” said Terry Ko, chief operating officer of California-based PV Circonomy.
Ko said PV Circonomy’s PV Circulator performs sequential layer-by-layer separation, preventing glass from being crushed into the silicon stream, and has achieved a 99.3% mass recovery rate by weight according to SGS certification cited by the company. Ko acknowledged that no industry-wide purity specifications for recycled PV silicon feedstocks currently exist, with downstream refiners developing their own acceptance criteria.
Obst agreed that mechanical processes face inherent limitations on silver recovery specifically – a view that could not be independently tested against commercial hydrometallurgical operators, none of which responded to requests for comment.
Thermal processing
Obst assessed thermal pyrolysis – an oxygen-limited thermal treatment that decomposes encapsulants – positively, drawing on a visit to a facility operated by Shinryo Corp., a Mitsubishi Chemical Group subsidiary that operates PV recycling plants in Japan. The Kitakyushu-based company’s process uses high-temperature treatment to break down encapsulants, enabling the recovery of glass and metals from end-of-life modules.
“After a pyrolysis process it simplifies subsequent separation of glass and silicon because the grain sizes of the material are very different,” he said.
At around $1,000/MT of PV waste, according to Obst, the process carries a significant cost premium over mechanical alternatives. French company ROSI Solar, which operates a commercial pyrolysis line in France and is scaling internationally, did not respond to requests for comment.
Recovering silicon at PV-grade purity faces two structural constraints, Obst said. Purification requires removing the phosphorus-doped emitter layer with hydrofluoric acid, a process that demands large quantities of the chemical and is costly at scale. The second constraint is the industry’s shift from p-type to n-type base material. “As the base dopant remains in the material, you would end up in materials that nobody wants today.”
A 2022 collaboration between Fraunhofer CSP and Fraunhofer ISE produced a passivated emitter and rear cell (PERC) with 19.7% efficiency from 100% recycled silicon, against 22% on virgin material in the same run. The project has not been publicly reported to have moved beyond the demonstration stage.
Missing modules
One anomaly remains unexplained. Despite subsidy-era installations approaching decommissioning age, Obst said PV waste volumes arriving at German recycling facilities have declined in recent years. Fraunhofer CSP attempted to trace the discrepancy through customs statistics but could not close the gap. “Where are those modules?” Obst said. “I have no idea.”
That uncertainty is the central problem for anyone planning recycling investment. Facilities will need to scale for a 2030s peak whose timing and magnitude remain unclear, then absorb years of lower throughput before volumes recover in the 2040s – a cycle that Obst said makes the business case difficult to model, let alone finance.
Obst suggested physical storage of incoming modules as one option to maintain stable processing throughput. Ko said PV Circonomy is developing a hardware-as-a-service model to deploy processing capacity closer to where modules are generated, and had held active discussions in Australia.
What the missing-modules anomaly ultimately underscores is a mismatch the IEA-PVPS noted as recently as May: solar recycling technology is advancing, but the economic infrastructure to deploy it at scale – and the waste volumes needed to make it viable – have not yet arrived together.
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German research institute Fraunhofer Institute for Solar Energy Systems (ISE) has increased the performance of its III-V germanium solar module from 34.2% to 34.4% through an optimised cell interconnection approach. 
According to the institute, this was achieved using shingle-matrix technology, which improves area utilisation and reduces shading losses by eliminating conventional cell interconnect ribbons. 
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The shingle-matrix technology was developed in collaboration with a German mechanical engineering partner. Under the approach, solar cells are cut into narrow strips and arranged in an overlapping shingle configuration before being connected with electrically conductive adhesives. The design allows direct cell-to-cell contact and removes the need for solder-coated copper ribbons commonly used in photovoltaic modules.  
According to the institute, eliminating traditional interconnects prevents active cell areas from being shaded, increasing the proportion of light-converting surface area within the module. 
For the latest achievement, project coordinator Azur Space Solar Power further developed its triple-junction III-V germanium solar cells, adapting technology originally designed for space applications to operate under the terrestrial solar spectrum. The cells were manufactured on wafer formats compatible with larger-scale production, while German microstructure specialist temicon supplied the anti-reflective coatings used on the module’s front glass.  
The latest result further strengthens Germany’s position in high-efficiency III-V photovoltaic research, a segment primarily associated with space and concentrator photovoltaic applications but increasingly being explored for terrestrial use. 
The record-setting module builds on a previous milestone reached earlier this year when a Fraunhofer ISE research team developed an 833 square centimetre module with an efficiency of 34.2% under the “Vorfahrt” research project. 
The record module will be displayed at Fraunhofer ISE’s booth (A1.440) during Intersolar Europe 2026, part of The Smarter E Europe exhibition in Munich.

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