Solar Now

First Solar upgraded at Freedom Broker as Section 232 seen driving upside (FSLR:NASDAQ)  Seeking Alpha
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Chinese PV technology manufacturer Trina Solar has launched an “Australia specific” variant of its Vertex S+ modules featuring a power output of 515 W and a maximum efficiency of 24.65%.
Image: Trina Solar
Trina Solar has unveiled a variant of its Vertex S+ (TSM-NEG10R.28Z) solar module series that it says is designed to deliver a higher output within standard rooftop constraints and is tailored specifically for Australia’s residential and commercial and industrial (C&I) market.
“The Australian-exclusive module has been designed to support systems up to 100 kW under Australia’s Small-scale Renewable Energy Scheme (SRES), where higher wattage and efficiency per module allows installers to optimise system size and maximise Small-scale Technology Certificate (STC) returns within physical roof constraints,” Trina said.
The Chinese manufacturer said the monofacial NEG10R.28Z module delivers up to 515 W output with a maximum conversion efficiency of 24.65% within a standard rooftop module footprint of 1842 mm x 1134 mm x 30 mm. Built on Trina’s latest n-type i-TOPCon ultra cell architecture, the module incorporates zero-busbar and zero-gap technologies that the company said enhance efficiency and minimise electrical losses.
“This higher power density allows installers to achieve target system capacity with fewer modules and support higher system capacity without increasing footprint,” Trina said. “This contributes to lower balance-of-system (BOS) requirements and improved levelised cost of electricity (LCOE).”
The module’s open-circuit voltage is 38.3 V and the short-circuit current 12.85 A with Trina declaring the lower-voltage design enables more flexible string sizing, allowing installers to optimise system layouts across a range of inverter configurations.
“This provides greater design flexibility in rooftop applications, particularly where system configuration is constrained by roof layout or electrical limits,” the company said.
Trina said the design also reflects Australian operating conditions, with a low temperature coefficient of -0.26%/°C to support performance in high heat, and a dual-glass structure to improve durability. The module is also engineered to withstand mechanical loads of up to 5,400 Pa (snow) and 4,000 Pa (wind).
The product is backed by a 25-year product warranty and 30-year power guarantee. End power output is guaranteed to be no less than 88.85% of the nominal output power, while degradation in the first year should not exceed 1%.
Edison Zhou, Trina’s head of operations in Australia and Asia Pacific, said the product reflects a shift in the Australian rooftop solar market towards system optimisation.
“We see 510-515 W range as the practical ‘sweet spot’ for Australian rooftop systems,” he said. “Installers are consistently looking for higher wattage, higher efficiency modules that fit standard module dimensions, particularly where system design is constrained by roof size and configuration.”
“This allows for greater system capacity within a given footprint, while maintaining flexibility in system design depending on inverter selection.”
The Vertex S+ 515W module is available for preorder and is expected to be available in Australia from early Q3 2026, subject to final certification and product listing requirements.
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Grand Design is recalling more than 1,200 model year 2025-2026 Lineage motorhomes. The epoxy adhesive securing the solar panels to the roof may fail, allowing the solar panel to detach. As many as 1,269 RVs may be affected by the recall, which was issued April 30.
The cause of the issue is inadequate adhesion due to incompatibility between the epoxy adhesive and the roof and panel.
A detached solar panel can become a road hazard for other vehicles, increasing the risk of a crash and injury. For a motorhome’s driver, there is little or no warning that there is a problem.
Dealers will install mechanical fasteners, free of charge. Owner notification letters are expected to be mailed June 24.
Owners may contact Grand Design customer service at 1-574-825-9679. Grand Design’s number for this recall is M910059. This recall supersedes NHTSA recall 26V042.
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Media networks reported on May 3 that some lawmakers proposed looking into unregistered or informal solar installers over safety and regulatory compliance concerns.

Cristina Eloisa Baclig

Philippine Daily Inquirer

View all posts by Cristina Eloisa Baclig →

Philippine Daily Inquirer
View all posts by Cristina Eloisa Baclig →
Solar panel installation composite image. PHOTO: PHILIPPINE DAILY INQUIRER
May 6, 2026
MANILA – Calls to investigate so-called “guerrilla” solar installers have renewed attention on how the Philippines manages access to energy, particularly as more households turn to alternative sources amid high electricity costs.
Media networks reported May 3 that some lawmakers proposed looking into unregistered or informal solar installers over safety and regulatory compliance concerns.
The proposal has drawn mixed reactions, with some stakeholders raising questions about whether tighter oversight could affect the pace of renewable energy adoption, particularly at the household level.
RELATED STORY: Solar panel installers urged to register with DOE
For University of the Philippines Diliman professor and Inquirer data scientist Dr. Rogelio Alicor Panao, the discussion points to a broader tension shaping the country’s energy landscape.
“Recent calls for Congress to investigate ‘guerrilla’ solar installers highlight the friction between monopoly control and energy democratization,” he said, noting how the framing of the issue can influence both policy direction and public perception.
He added that the language used to describe these installers may carry unintended implications.
“While framed as a safety concern, the ‘guerrilla’ label not only unfairly stigmatizes citizens seeking relief from some of Asia’s highest electricity rates, but also casts doubt on motive since monopolies stand to gain the most when decentralized competition is strictly curtailed,” he said.
Untapped potential and structural barriers
Data from the World Bank reinforces the idea that the country’s challenge is not a lack of solar resources. The Philippines posts a practical photovoltaic potential (PVOUT) of 3.93 kWh per kWp per day—placing it in the midrange globally but among the stronger performers in Southeast Asia.
As Panao pointed out, “Our solar potential is nearly 10% higher than Vietnam’s (3.55) and is neck-and-neck with Thailand (4.06).”
Yet this relative advantage has not translated into widespread adoption. Looking at broader development patterns, Panao noted that countries with strong solar potential often face structural constraints that limit their ability to capitalize on it.
“The data also reveals a negative correlation (-0.43) between solar potential and the Human Development Index (HDI), indicating that nations with the most to gain from solar often face the highest systemic barriers,” he said.
In the Philippines, where the HDI stands at around 0.70, these constraints take on added significance.
“For the Philippines, where the HDI is approximately 0.70, solar is not a luxury but a critical tool for development that remains capped by a regulatory environment seemingly designed to preserve the status quo,” he said.
Rather than viewing the issue solely through enforcement, Panao’s analysis points to policy gaps that shape both large-scale and small-scale adoption. If the goal is to expand access to solar energy, he said, reforms will need to address bottlenecks across the system.
“If Congress is truly serious about tapping the Philippines’ solar potential, it can explore the following as policy actions,” he said, outlining measures that range from streamlining approvals to supporting decentralized systems.
RELATED STORIES: DOE drafts registration rules for solar PV system vendors
Among these is the need to ease permitting for utility-scale projects by establishing administrative “one-stop shops” and enforcing strict processing timeframes to eliminate the red tape that continues to stall large-scale deployment.
At the same time, Panao underscored the importance of ensuring that smaller producers—now an increasingly visible part of the energy mix—are supported rather than constrained.
“Second, it should establish a balanced policy environment for distributed photovoltaic systems that protects small-scale producers rather than penalizing them,” he said.
In an archipelagic country like the Philippines, decentralized systems take on added importance, particularly in expanding access to areas beyond the reach of traditional grids.
“Third, the government must support the adoption of decentralized off-grid and mini-grid systems, which are the most cost-effective way to bring power to remote island communities and provide urban backup,” he said.
Sustaining that momentum, Panao said, will depend not only on expanding access but also on keeping solar technologies affordable and better integrated into the grid.
“Finally, by maintaining the cost-reduction trajectory for solar components and supporting the development of smarter inverter systems for better grid integration, the Philippines can transition solar energy from a marginalized, unregulated activity into a primary energy right for every citizen, ensuring that clean power is accessible to the public rather than restricted by dominant market interests,” he said.
RELATED STORY: EXPLAINER: How to keep your solar panels safe from fire
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China Energy Engineering Corporation has successfully connected the 30 MW Dekemhare Solar Plant to Eritrea’s national grid at full capacity in Dekemhare, marking a significant milestone in the country’s power sector development and its transition toward cleaner energy systems.
The facility is now the largest solar installation in Eritrea and the first centralised renewable energy plant in the country to be paired with a utility scale battery energy storage system rated at 15 MW with 30 MWh capacity. The integration of storage with solar generation is expected to significantly enhance grid stability by managing variability in solar output and ensuring more consistent electricity supply.
The project more than doubles Eritrea’s existing solar generation capacity and represents a strategic shift away from dependence on diesel powered generation, which has historically been both costly and environmentally intensive. By displacing diesel generation, the plant is expected to reduce fuel import requirements while improving overall energy security.
Located in Dekemhare, an area known for strong solar irradiation levels, the installation is positioned to maximise generation efficiency and support broader electrification objectives in the region. The combination of high resource availability and integrated storage provides a practical model for scaling renewable energy deployment in similar markets across Africa.
The addition of battery storage allows excess daytime solar energy to be stored and dispatched during peak demand periods, reducing intermittency challenges that often limit renewable energy penetration. This capability is particularly important for emerging power systems seeking to balance reliability with rapid expansion of renewable capacity.
The commissioning of the Dekemhare Solar Plant highlights the growing role of hybrid renewable energy and storage solutions in supporting energy access and grid modernisation efforts in Africa’s developing power markets.
Author: Bryan Groenendaal






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The Ministry of New and Renewable Energy (MNRE), in its seventh Approved List of Module Manufacturers (ALMM) for solar cells, has added Renewsys India Pvt. Ltd. and revised the solar cell manufacturing capacity for Waaree Energies, marking another update in India’s approved domestic manufacturing base.
MNRE has enlisted Renewsys India Pvt. Ltd. with a manufacturing capacity of 452 MW per year for its bifacial N-type TOPCon solar cells (182.2 mm × 183.75 mm, 16 busbar, PID-free). These cells report an average efficiency of 24.60%, with an efficiency range of 24.00% to 25.60%. The wattage is specified at 8.23 W, ranging from 8.03 W to 8.54 W. The enlistment is valid from April 30, 2026, to April 29, 2030.
Waaree Energies has revised the enlisted capacity for its manufacturing unit in Chikhli, Navsari, Gujarat. The facility continues to hold an enlisted capacity of 1,328 MW per year, with updated performance metrics. The revised efficiency range now stands at 22.00% to 23.70%, with wattage ranging around 7.85 W (min–max). Earlier figures indicated an efficiency range of approximately 22.00%–23.70%, with previously noted wattages between 7.36 W and 7.85 W.
Continuing with the same capacity under the ALMM listing, where Waaree had reported an output of 1,328 MW per year for monocrystalline PERC (P-type) bifacial solar cells (182.2 mm × 182.2 mm, 10-busbar, PID-free). Now the company has revised the average efficiency of the cell to 23.55% and a wattage of 7.78 W, with an efficiency range between 22.20% and 23.50%. Similarly, continuing with Waaree’s earlier enlistment of 3,923 MW/year for its WSC-N-M10R-16BB mono TOPCon solar cells, but it has now revised the range of efficiency to 24.0% -25.80% and 8.00 W to 8.68 W.  
India had earlier seen India pass the 30 GW solar cell manufacturing mark, driven by fresh additions and capacity upgrades reflected in the latest update to the Ministry of New and Renewable Energy’s (MNRE) Approved List.
Among the key additions, Reliance Industries Limited has been enlisted for its Jamnagar, Gujarat facility with a capacity of 1,238 MW per year for advanced heterojunction (HJT) solar cells (210 mm × 105 mm, no busbar, PID-free). These high-efficiency cells deliver an average efficiency of 25.40% with a wattage of 5.60 Wp per cell. The enlistment remains valid from April 13, 2026, to April 12, 2030.
Jupiter Solartech Private Limited secured its third enlistment under ALMM-II, adding around 991 MW per year of mono PERC bifacial solar cell capacity. This builds on earlier enlistments of Jupiter International Limited (Units 1 and 2), which had added 339 MW and 440 MW per year, respectively, in June 2025 at its Baddi facility in Himachal Pradesh. The company has now expanded further with Unit III in the same industrial cluster.
Meanwhile, Websol Energy System Limited has scaled up its enlisted capacity to 1,202 MW per year at its Falta Special Economic Zone facility in West Bengal. The upgraded capacity covers mono-crystalline PERC (P-type bifacial) cells in 182.2 mm × 182.2 mm and 182.2 mm × 183.75 mm formats (10 busbar, PID-free) under the WS182MP10 category. These cells achieve an average efficiency of 23.55% with a wattage of 7.77 W, and operate within a range of 19.00% to 23.60% efficiency and 6.29 W to 7.88 W.
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Solar Power World
By Kelly Pickerel | May 5, 2026
The Sun Pond solar and storage project in Maricopa County, Arizona, is now online. The 111-MW solar and 340-MWh storage project was developed by Longroad Energy and constructed by McCarthy Building Companies. 
Two California utilities, Ava Community Energy and San José Clean Energy (SJCE), have contracted for the output of Sun Pond via long-term PPAs.
“With Sun Pond now operational, Longroad is pleased to be expanding access to renewable energy for customers in the greater Bay Area,” said Charles Spiliotis, Chief Investment Officer and co-founder of Longroad Energy. “Sun Pond’s battery storage system adds firm, flexible capacity – ensuring low-cost, clean power is available when the grid needs it most.”
Sun Pond is part of the Longroad Sun Streams Complex, a four-project complex totaling nearly 1.6 GW of solar and storage capacity  in Maricopa County, Arizona. The entire Longroad Sun Streams Complex is providing more than $300 million in benefits to Arizona schools and communities through its long-term leases with the Arizona State Land Department and tax remittances.
Longroad employed the Gridstack battery energy storage system from U.S.-based energy storage platform provider Fluence for the Sun Pond BESS. Sun Pond utilizes First Solar’s PV modules, Nextpower’s smart trackers and Sungrow’s solar inverters.
McCarthy was the EPC contractor. More than 300 people were employed across all contractors and teams at peak construction. NovaSource Power Services and Longroad’s affiliate Longroad Energy Services will provide comprehensive operations and maintenance services.
News item from Longroad
Kelly Pickerel has more than 15 years of experience reporting on the U.S. solar industry and is currently editor in chief of Solar Power World. Email Kelly.

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EDP Weighs Sale of US Unit Focused on Small-Scale Solar Power  Bloomberg.com
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The Madison College chapter of the National Society of Leadership and Success recently inducted 14 new members during its spring induction ceremony…
Madison College recently marked a sustainability milestone with a ribbon-cutting ceremony for its new solar plus energy storage system at the Truax Campus Protective Services Building.
The solar project is designed to enhance reliability, reduce environmental impact and help lower operating costs.
Along with these benefits, the system also offers a hands-on learning laboratory for students and educators.
“At our campuses, students gain hands-on experience with innovative technologies that prepare them for clean energy careers,” said Dr. Jennifer Berne, Madison College president. “At the same time, we are advancing sustainable, reliable energy solutions for our region.”
The April 20 ribbon-cutting ceremony was part of a series of “Earth Week” events held at the college. Other activities included a sustainability tour, free bike tune-ups, a sustainability fair and trash pick-up throughout the campus.
Features of the new large-scale battery energy storage installation at the Protective Services Building include:
The project will offer an opportunity for students to study solar performance in programs such as Renewable Energy Certificate, Electrical Apprenticeship, Electrical Technical Diploma, Construction Technical Diploma, Industrial Maintenance AS, Electromechanical Technology AS and Architecture AS.
“This solar plus storage installation provides infrastructure for training students for skilled technical careers in the energy workforce,” said Madison College instructor Ken Walz.
The $665,000 solar plus energy storage project was supported in part by a $435,000 award from the Wisconsin Energy Innovation Grant Program.
“The project demonstrates Madison College’s commitment to protecting our planet, responsibly stewarding our operations and advancing our mission to serve students,” said Dr. Sylvia Ramirez, the college’s executive vice president of finance and administration.

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The Ann Arbor Sustainable Energy Utility will use locally sited solar, batteries and other resources to improve reliability and lower costs for subscribers, city officials say.
The homes participating in the pilot program are located in Ann Arbor’s Bryant neighborhood, where A2SEU held a March meeting seeking residents willing to become its first customers.
Bryant has more energy-burdened residents than Ann Arbor as a whole, with some locals spending upwards of one-third of their household income on utility bills, FranklinWH said. Neighborhood median income is well below the citywide average, according to local media outlet MLive.
At the meeting, Jordan Larson, engagement innovator with the city of Ann Arbor’s Office of Sustainability and Innovations, showed a chart illustrating how enrolled homes would self-consume some of the power generated by their panels and store the rest in batteries for discharge during the evening and overnight hours.
“All of the work in this project is focused on reducing total energy costs,” Larson said.
In 2024, nearly 80% of Ann Arbor voters approved a referendum to create a city-owned utility that would help accelerate the city’s clean energy goals and boost local resilience. The Bryant solar-plus-storage pilot is the first step toward a future that A2SEU says could feature microgrids, geothermal heating and cooling networks, and energy justice initiatives for the roughly 125,000 inhabitants of the university town 40 miles west of Detroit.
“Unlike a traditional utility, we are only going to offer renewable energy products, including solar and geothermal that will come later to this neighborhood and hopefully all around the city,” Shoshannah Lenski, A2SEU’s executive director, said at the March meeting.
A spokesperson for DTE Energy, the investor-owned utility that serves Ann Arbor, Detroit and surrounding communities, said it supports A2SEU’s sustainability goals in a statement comparing the municipal program to DTE’s own voluntary clean energy program.
“When coupled with DTE’s planned investments in clean energy, these voluntary, fee-based programs help accelerate economy-wide decarbonization while maintaining reliability and affordability,” Ryan Lowry, the spokesperson, said in an email.
A2SEU says energy storage will help its subscribers ride through power outages and — along with other onsite power generation — boost overall system reliability by “[minimizing] the need for distribution systems (e.g., poles and wires), which are currently the most vulnerable part of the existing energy system.”
A 2025 report from the Citizens Utility Board of Michigan, a utility watchdog group, found Michigan’s power grid experienced longer-duration outages over the past five years than all but a handful of other states. DTE is spending billions to upgrade its distribution grid and says its reliability has improved significantly since 2023.
Lowry said DTE’s “five-year, $270 million plan to modernize the electric system that serves the city” helped it deliver “the best electric reliability Ann Arbor has experienced in nearly 30 years” in 2025.
For the time being, A2SEU enrollment is optional for Ann Arbor residents and its generating resources supplement rather than replace DTE’s assets. But a citizen group calling itself Ann Arbor for Public Power is gathering signatures for a November ballot initiative that could start the years-long process of creating a full-fledged public utility in the city. DTE has spent nearly $2 million opposing the effort, according to financial disclosures reviewed by MLive.
Lowry said “municipalization” in Ann Arbor would cost residents and taxpayers $1 billion upfront and increase energy bills in the city by a “minimum” of 30% to 40%, per a DTE-commissioned report released in early 2025.
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The PJM Interconnection’s planned backstop auction is flawed, said CEO Brian Tierney. Separately, Pennsylvania Gov. Josh Shapiro said his administration will oppose rate hike requests that fail to meet affordability criteria.
The reliability watchdog is concerned about a series of “widespread and unexpected” customer-initiated load reductions in 2024 and 2025 during which 1,000 MW or more dropped off the bulk power system.
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The PJM Interconnection’s planned backstop auction is flawed, said CEO Brian Tierney. Separately, Pennsylvania Gov. Josh Shapiro said his administration will oppose rate hike requests that fail to meet affordability criteria.
The reliability watchdog is concerned about a series of “widespread and unexpected” customer-initiated load reductions in 2024 and 2025 during which 1,000 MW or more dropped off the bulk power system.
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Scientific Reports volume 16, Article number: 12293 (2026) Cite this article
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This study analyzes the power production (PP) and energy yield of four 100 kW PV subfields, consisting of monocrystalline and polycrystalline technologies, with fixed and single-axis tracking systems. All subfields are installed at a 30° inclination, close to the region’s optimal angle. Actual performance data were recorded every four minutes in OUED-NECHOU, Ghardaïa, over four experimental days in 2016, each representing a different season. The results indicate that single-axis tracking subfields consistently outperformed fixed systems throughout the diurnal cycle by generating more power and enhancing overall performance. However, on May 1^st, the fixed mc-Si and pc-Si subfields reached peak outputs of 95.67 kW and 84.06 kW, respectively, surpassing the motorized subfields, which recorded 88.35 kW and 83.01 kW. Conversely, on July 1^st, the single-axis tracking systems achieved their highest daily energy generation, with the mc-Si subfield producing 787.94 kWh/day and the pc-Si single-axis system generating 715.17 kWh/day. Further analysis of mean power output augmentation demonstrated that single-axis tracking subfields consistently outperformed their fixed counterparts, which served as the baseline across all experimental days, with the highest gains observed in east–west tracking systems. On July 1^st, the mc-Si tracking system achieved a 19.22% increase over the fixed mc-Si subfield, while the pc-Si tracking subfield exceeded its fixed counterpart by a remarkable gain of 21.44%. Moreover, tracking systems exhibited a clear advantage in maximizing solar energy capture, leading to higher energy production. Finally, the impact of weather conditions, including solar irradiance, temperature, wind speed, and relative humidity, on PV subfield power generation was experimentally analyzed.
Energy production presents a significant challenge for the near future. Currently, fossil fuels remain the primary source of global energy, contributing heavily to greenhouse gas emissions and accelerating climate change. The rapid depletion of these finite resources, due to excessive consumption, emphasizes the need for sustainable alternatives Haddad et al.¹ and Saiah and Stambouli². In this context, the demand for renewable energy sources has become increasingly urgent. Renewable energy, particularly solar, wind, and hydropower, is gaining recognition as a viable solution to meet the rising global energy demand. However, the intermittent nature of these sources necessitates efficient and cost-effective energy storage solutions. Zhang et al.³ presented a thorough review of iron-based redox flow batteries (Fe-RFBs), which are becoming a promising solution for large-scale energy storage. Their study examined the historical development, essential performance factors, and recent advancements in Fe-RFB technology. It emphasized the advantages of Fe-RFBs, including their cost-effectiveness, environmental benefits, and potential to facilitate the integration of renewable energy sources. The findings highlighted that iron-redox flow batteries (Fe-RFBs) have advantages such as a long cycle life and scalability, but they still face challenges. These challenges included mitigating hydrogen evolution, improving electrode stability, and enhancing overall efficiency. To tackle these issues, the authors recommended optimizing electrode materials, developing cost-effective active components, and refining system design to boost performance and commercial viability. These advancements have the potential to significantly improve energy storage capacity, thereby contributing to the stability and sustainability of renewable energy systems.
These advancements could significantly improve energy storage capacity, Promoting the stability and sustainability of renewable energy systems and given the increasing reliance on solar energy, integrating efficient energy storage benefits, particularly in sun-rich regions like Algeria.
With its exceptional year-round sunshine, Algeria is well-positioned for large-scale solar energy deployment⁴. In recent years, government initiatives have driven significant progress in renewable energy, including establishing of photovoltaic power plants in the Saharan regions to enhance solar capacity. For example, as part of its renewable energy strategy for the Saharan regions, Sonelgaz (The National Gas and Electricity Society) has established photovoltaic power plants in the OUED-NECHOU region of Ghardaïa. These plants, managed by SKTM (Electricity & Renewable Energy Company), have a combined production capacity of approximately 1.1 MW. Ensuring that these photovoltaic modules operate reliably for 20–25 years under field conditions is critical to maintaining profitability⁵. This initiative underscores Algeria’s commitment to clean energy and sustainable development, paving the way towards a greenr and more eco-friendly future Dahmoun et al.⁶. Understanding the performance of photovoltaic (PV) systems is essential for evaluating the potential of solar energy as a reliable power source. Analyzing the efficiency and operation of these systems provides valuable insights into their maintenance needs and long-term economic viability Dahmoun et al.⁶. PV systems rapidly emerged as a dominant sustainable electricity source, representing a promising alternative to conventional energy sources. Their performance, however, depends largely on the technology used and the system’s design. Numerous studies have assessed PV plant performance in various geographic regions, emphasizing how local environmental conditions influence system efficiency. Large-scale photovoltaic public–private partnership (LS-PVPP) projects have been analyzed globally, with findings from some reported in the literature Ascencio-Vasquez et al.⁷. Bentouba et al.⁸. For instance, Shiva Kumar and Sudhakar⁹, studied a 10 MWp photovoltaic plant in India, reporting a yield factor (YF) ranging from 1.96 to 5.07 h per day, an annual performance ratio (PR) of 86.12%, and a capacity factor (CF) of 17.68%, with an annual energy generation of 15,798.192 MWh. Similarly, Touili et al.¹⁰. They found that a 100 MWp plant in the MENA region produces an average of 158 GWh annually. In comparison, the same configuration generates 155.8 GWh annually in Almeria, Spain, and 155.4 GWh in Bakersfield, California. Maximizing the performance of photovoltaic (PV) solar panels relies on capturing as much sunlight as possible. Solar tracking systems are a key technology in achieving this, as they enable PV panels to continuously align with the sun’s movement. By adjusting along vertical or horizontal axes, these systems optimize electricity production by ensuring that the panels are always positioned to capture maximum sunlight. As noted by Gomez-Uceda et al.¹¹. Photovoltaic plants equipped with sun tracking systems are designed to follow the sun’s trajectory, ensuring that panels remain perpendicular to the solar rays throughout the day, thereby maximizing power generation. Numerous studies have analyzed the efficiency of solar tracking systems compared to fixed installations. George et al.¹². Two off-grid PV systems in Italy one fixed and the other equipped with a daily single-axis solar tracker were analyzed. Their results indicated higher power production in the morning and evening with the single-axis tracker, in contrast to the fixed system. This supports the broader consensus in the literature that tracking systems consistently outperform fixed PV systems in terms of energy generation Nsengiyumva et al.¹³, Chien-Hsing et al.¹⁴. Further studies by Zaghba et al.^15,16 demonstrated that solar tracking systems significantly increase energy capture compared to stationary systems. Vaziri Rad et al.¹⁷ examined various tracking systems across different regions of Iran, finding that twin-axis trackers increased energy generation by 32%, while single-axis trackers led to a 23% increase compared to stationary systems. These findings highlight the critical role of tracking technology in enhancing the efficiency and overall performance of photovoltaic power plants. Recent literature documents both significant advances and practical challenges in solar tracking technologies. The comprehensive review by Kumba et al.¹⁸ summarizes performance gains achievable with modern trackers while also highlighting the trade-offs of increased mechanical complexity, maintenance requirements, and the need for robust control algorithms. Empirical work on alternative mechanical architectures such as the second-order lever single-axis tracker evaluated by Kumba et al.¹⁹ demonstrates that innovative designs can improve solar capture and reduce actuator demands under real field conditions. Field studies in high-irradiance environments, such as the Manta, Ecuador case study Ponce-Jara et al.²⁰, further confirm that well-designed single-axis tracking systems can significantly increase daily and long-term energy yield, especially when tailored to local irradiance and operational constraints. In addition, recent work by Kumba et al.¹⁹ investigated second-order lever single-axis solar tracking systems, demonstrating improved energy output over conventional trackers. While partial shading was not specifically studied, the results highlight the potential of optimized mechanical architectures to enhance energy capture under dynamic solar angles. In harsh desert-type climates such as OUED-NECHOU—characterized by high irradiance, dust accumulation, and occasional shading—these design principles are particularly relevant. Building on these concepts, our experiments indicate that optimized single-axis tracking systems, incorporating features inspired by second-order lever architectures, can substantially increase long-term daily energy production. Local factors such as dust storms, ambient temperature fluctuations, and maintenance logistics must guide system selection and operation. Overall, our study confirms that advanced tracking technologies, when adapted to site-specific conditions, can improve energy yield and system resilience in Saharan regions. Recognizing that efficiency and performance are essential aspects of a PV system’s functionality, they have been the focus of an extensive body of literature. Numerous studies Pendem and Mikkili²¹, Kumar et al.²², Bahanni et al.²³, Kawajiri et al.²⁴ emphasize that various factors, including solar irradiance, ambient temperature, module temperature, wind speed, relative humidity, materials, and the mounting of PV modules. Caouthar Bahanni et al.²⁵ conducted a comparative analysis of the energy performance and the influence of meteorological conditions on three photovoltaic technologies (monocrystalline, polycrystalline, and amorphous) installed in two Moroccan cities, Beni Mellal and El Jadida. Using data from one year of operation (January to December 2017), the study assessed the production performance of identical PV stations in distinct climates. The results demonstrated that photovoltaic performance is strongly influenced by meteorological factors. Solar irradiation was identified as the dominant factor, with higher irradiation directly increasing output. Temperature also had a significant impact; rising temperatures led to a reduction in PV cell voltage and power output. Wind speed provided moderate benefits by cooling the panels, slightly improving efficiency, while humidity had the least impact, primarily affecting production through cloud cover. Notably, polycrystalline panels exhibited the highest performance in Beni Mellal, followed by monocrystalline, with amorphous panels being the least efficient. Temperature significantly influences the energy output, power output, and overall efficiency of photovoltaic systems. Amelia et al.²⁶ conducted research that conclusively demonstrates that as module temperatures increase, the output power and efficiency of PV panels decrease. Karami et al.²⁷ conducted a study on the performance of monocrystalline, polycrystalline, and amorphous solar modules installed on the rooftops of an educational institute in Morocco. The results showed that the maximum performance ratio (PR) achieved was 72.10%, 91.53%, and 86.20% for cloudy days due to low temperature and high wind speed. Conversely, the minimum PR values and PV module efficiency were observed on quiet sunny days and rainy days, impacting the energy generated. The significance of module temperatures in the performance of solar PV systems is highlighted in the articles by Malvoni et al.²⁸. Al-Maghalseh²⁹, and Kumar et al.³⁰. To accurately evaluate the performance of PV systems, various models, such as those proposed by Correa-Betanzo et al.³¹ have been suggested for estimating module temperatures. A comparative study by Olukan and Emziane³² examines 16 temperature models based on monthly mean meteorological data. The investigation analyzes how module temperatures fluctuate in response to changes in solar irradiation ranging from 100 to 1000 W/m² and varying ambient temperatures. The results indicate a temperature range for the modules from 31.8 to 66 °C across different months. The study emphasizes the performance differences among the models, underscoring the appropriateness of each model for the optimal sizing and design of PV systems. Additionally, Wind speed is a crucial parameter that significantly affects photovoltaic (PV) system performance. While its impact on power production can vary, wind plays a vital role in cooling solar panels, which enhances overall energy output by improving module efficiency. For instance, Balta et al.³³ observed that consistent wind on PV panel surfaces positively influenced both cooling and the cleaning of dust deposits in Amasya, Turkey. Similarly, Al-Bashir et al.³⁴ found that increased wind speed resulted in lower cell temperatures, subsequently boosting output power in PV systems installed in Jordan. Humidity, on the other hand, negatively impacts the performance of PV systems. Water droplets in the air and condensation on panel surfaces diminish the solar irradiation reaching the modules, thereby affecting their efficiency. Ramli et al.³⁵ conducted experiments under various weather conditions dusty, cloudy, and rainy in Surabaya, Indonesia, demonstrating performance loss associated with these factors. Furthermore, heightened air humidity often leads to persistent cloud cover, complicating solar energy production. Despite this, humidity remains a significant variable influencing the performance of photovoltaic systems. Building on these findings, numerous studies have explored critical comparisons between fixed and sun-tracking photovoltaic systems, assessing their efficiency, energy yield, and operational effectiveness. Research also includes performance evaluations of PV systems across different climates, large-scale experimental assessments, and the impact of temperature and irradiation on energy production. Furthermore, advanced approaches such as PV cooling techniques and energy-exergy analysis have been examined to enhance system efficiency. Moreover, experimental studies conducted at large-scale PV centers across different regions provide valuable insights into real-world system performance. To effectively highlight key findings, the following literature review table provides a structured summary of relevant studies, emphasizing their contributions to PV system performance analysis and identifying gaps for future research. This tabular presentation systematically outlines the research gaps and the contributions of this study, clearly illustrating the novelty of our work (Table 1).
This study aims to provide a comprehensive analysis and evaluation of the performance of four photovoltaic subfields, each employing different configurations: two single-axis tracking systems and two fixed systems, incorporating both monocrystalline (mc-Si) and polycrystalline (pc-Si) silicon technologies. Conducted in the Saharan environment of OUED-NECHOU, Ghardaïa, at the SKTM Electricity and Renewable Energy Company unit, this research examines performance under actual weather conditions rather than Standard Test Conditions (STC). The study focuses on key performance metrics, including peak output power (kW), long-term daily power production (kW), and the average daily output power (kW) over each of the four observed days, accounting for seasonal variations. It also evaluates the performance improvement of single-axis tracking systems compared to fixed photovoltaic subfields, with a focus on the gain in output power expressed as a percentage (%). To ensure precise data collection and analysis, daily energy generation (kWh/day) was measured at four-minute intervals. Additionally, this research examines the influence of real-time weather data, recorded at the same intervals, on subfield performance. Key factors include solar irradiation at a 30° tilt (W/m²), ambient temperature (°C), module temperature (°C), wind speed (m/s), and relative humidity (%). The analysis considers seasonal climatic variations and their influence on these meteorological parameters throughout specific experimental days in winter, spring, summer, and fall. A section of this study intends to predict the total solar radiation flux at a 30° tilt using semi-empirical models, specifically the PERRIN DE BRICHAMBAUT model. The expected results will be compared with experimental data recorded in real-time at four-minute intervals over four measured days: January 1^st, May 1^st, July 1^st, and October 1^st, each representing a different season. Data was collected from a weather station installed on the roof of the photovoltaic station’s control room. Statistical indicators used for comparison between the estimated and measured data include the Absolute Error curve (AE) , Mean Absolute Error (MAE, W/m²), Root Mean Square Error (RMSE,W/m²), Correlation Coefficient (CC), and Mean Absolute Percentage Error (MAPE, %). the objective is to determine if the empirical model aligns most closely with the real data based on these statistical tests.
The Ghardaïa photovoltaic solar power plant, located in southern Algeria, is part of the renewable energy development program initiated by the supervisory ministry. It is situated near the village of OUED-NECHOU, 15 km north of Ghardaïa along National Road No. 01 as in Fig. 1, with a nominal power capacity of approximately 1100 kWp. The site is bordered by National Road No. 01 to the north and west, and vacant land to the east and south. The plant’s precise coordinates are 32°34′43.79’’ N latitude and 3°41′55.36’’ E longitude, at an altitude ranging from 450 to 566 m. The closest wilayas are Laghouat and Ouargla. The topography of the site is relatively flat, with a gentle east–west slope.
Geographical location of the photovoltaic power plants: 1.1 MWp OUED-NECHOU, Ghardaïa City ⁴⁶.
Ghardaïa’s hot, dry climate presents extreme environmental conditions, with temperatures ranging from − 5 to + 50 °C in the shade. Wind speeds can reach up to 28 m/s, and the maximum recorded relative humidity is 74% at 25 °C. Solar irradiations during the summer months can reach 900–1000 W/m². The area also experiences significant temperature fluctuations between day and night 15 to 20°C and frequent winds carrying fine sand particles, factors critical for plant design and maintenance. Despite these challenges, the plant is located in seismic zone 0, indicating low seismic risk as per Algerian regulations (RPA 99).
Researchers and professionals in photovoltaic technology and power plant performance emphasize the importance of understanding regional environmental conditions. Constance Kalu et al.⁴⁷ utilize 22 years of meteorological data from NASA’s global database, including solar insolation and air temperature, to perform a comparative analysis of polycrystalline, monocrystalline, and thin-film PV technologies using PVsyst version 5.21. Similarly, Allouhi et al.⁴⁸ employed METEONORM 7 data, including wind velocity, ambient temperature, and solar irradiance, to compare the performance of monocrystalline and polycrystalline PV technologies. Their study evaluates a 2 kWp grid-connected PV plant in Meknes, Morocco, combining recorded data from 2015 and simulated results to assess the power generation capabilities of these technologies. Al-Otaibi et al.⁴⁹ assessed the performance of CIGS thin-film PV systems installed on rooftops in Kuwait by monitoring key meteorological parameters such as solar radiation, ambient temperature, wind speed, and module temperature. Using a reference cell and pyranometer for solar radiation measurements, the study recorded data at five-minute intervals over twelve months to evaluate the impact of environmental factors on PV system efficiency in Kuwait’s climate.
It is crucial to have accurate weather data to evaluate and optimize the performance of photovoltaic systems. This necessitates using advanced technical instruments to gather experimental data on local weather conditions.
The meteorological station’s data acquisition system is installed on the rooftop of the Technical Room at the photovoltaic power plant. It is equipped with devices that provide essential climatic information, including 30° tilted solar irradiance (W/m²), ambient temperature (°C), wind speed (m/s) and direction, and relative humidity (%). Data were collected every 4 min from 06:00 AM to 19:52 PM on January 1^st, May 1^st, July 1^st, and October 1^st, representing different seasons (Winter, Spring, Summer, and Fall). Table 2 shows a list and specifications of instruments used by manufacturers.
Figure 2 presents experimental relative humidity data measured with a thermo-hygrometer over four days, from 06:00 AM to 19:52 PM. Each curve corresponds to a different day. The data reveal a consistent diurnal pattern, with higher humidity levels in the early morning and night, decreasing during the day and late afternoon, indicating a regular daily cycle. On October 1^st, relative humidity peaked at 90% at 06:00 AM, gradually reducing to 42% by 19:52 PM. A similar trend was observed on January 1^st, where humidity started at 67% at 06:00 AM and dropped to 45% by 19:48 PM. On May 1^st and July 1^st, relative humidity was significantly higher in the early morning, with readings of 42% at 06:00 AM on May 1st and 35% at the same time on July 1^st. Throughout the day, humidity levels steadily decreased, reaching 17% by 19:52 PM on May 1st and dropping to 10% by 19:52 PM on July 1^st (Figs. 3, 4).
Relative humidity data (%) over four experimental days , each representing a different season in 2016 .
Wind speed data (%) recorded over four experimental days, each representing a different season in 2016.
PERRIN DE BRICHAMBAUT estimated inclined solar radiation compared with experimental data on January 1^st 2016, a winter day.
The variation in humidity levels is due to the significant diurnal temperature fluctuations in the OUED-NECHOU region Figs. 5, 6, and 7. Intense heating during the day can lead to very low relative humidity, while in the early morning and at night, temperatures drop sharply, causing a brief rise in relative humidity. The RH data inversely correlates with the daily temperature cycle: as temperature increases, RH decreases, and vice versa.
PERRIN DE BRICHAMBAUT estimated inclined solar radiation compared with experimental data on May 1^st 2016, a spring day.
PERRIN DE BRICHAMBAUT estimated inclined solar radiation compared with experimental data on July 1^st 2016, a summer day.
PERRIN DE BRICHAMBAUT estimated inclined solar radiation compared with experimental data on October 1^st 2016, a fall day.
Figure 3 showcases experimental wind speed data from 06:00 AM to 19:52 PM over four days, each curve represents data from a different season, measured using an anemometer.
On January 1^st, the wind speed starts at a low of 0.02 m/s at 6:00 AM and reaches a peak of 2.56 m/s in the late afternoon at 6:32 PM. On May 1st , the wind speed peaks at 8.37 m/s in the early morning around 6:04 AM and again at 9:16 AM, then drops to 4.16 m/s by late afternoon around 7:48 PM. On July 1^st, the wind speed shows a rapid increase from 7.22 m/s in the early morning at 6:00 AM to 9.05 m/s by 7:24 AM, then decreases rapidly to reach 1.03 m/s, the lowest value recorded on that day, at 6:08 PM. On October 1^st, the wind speed peaks at 7.20 m/s around noon and drops to 2.67 m/s by late afternoon at 7:48 PM.
Wind speed changes are influenced by temperature variations. In summer, intense heat from the Sahara desert causes air to rise, creating low pressure and stronger winds, as observed on July 1^st. In winter, the smaller temperature difference between the desert and surrounding areas leads to weaker pressure gradients and lower wind speeds, as seen on January 1^st.
Figures 2 and 3 illustrate an inverse relationship between relative humidity (%) and wind speed (m/s) in the OUED-NECHOU region. High wind speeds with low humidity are observed in spring and summer (May 1^st and July 1^st), while low wind speeds with high humidity occur in winter and fall (January 1^st and October 1^st). This indicates that as wind speed increases, relative humidity decreases, and vice versa.
Photovoltaics offer a clean and promising energy solution, making the study of solar resources crucial for this field. A 2017 case study by Bill Marion and Benjamin Smith⁵⁰ developed a method for estimating solar radiation using PV module data with microinverters, validated with data from five systems in Golden, Colorado. The study accurately extracted direct normal irradiance (DNI) and diffuse horizontal irradiance (DHI), which are essential for developing and modeling PV projects in the region.
Various semi-empirical models documented in the literature have been extensively employed to investigate solar radiation on both horizontal and inclined surfaces.
A study conducted in Ouargla, which has similar climatic conditions to our study area, OUED-NECHOU in Ghardaïa, was carried out by Abdelmoumen Gougui et al.⁵¹. The study compared three models (CAPDEROU, PERRIN DE BRICHAMBAUT, and Hottel) for predicting total solar flux on horizontal surfaces using data from a weather station at the LAGE laboratory, Ouargla University. The data was recorded on the 15th of March, April, May, and October. The models were evaluated using RMSE, CC, and MAPE metrics in MATLAB. The results showed that the PERRIN DE BRICHAMBAUT and CAPDEROU models exhibit greater effectiveness under clear skies in Ouargla, demonstrating a high degree of accuracy and correlation between observed and predicted global solar radiation, this model outperforms the Hottel model. Additional studies on horizontal solar radiation across various regions offer further insights and findings^52,53,54,55.
Abdelatif Takilalte et al.⁵⁶ developed a methodology to estimate global tilted irradiation at 5-min intervals using only global horizontal irradiation data. This approach integrates the PERRIN DE BRICHAMBAUT and LUI & JORDEN models, adjusted for cloudiness factors, to create an anisotropic model. The proposed model demonstrated high accuracy across various metrics, including nRMSE (4.7–6.41%), RPE (5.5–5.9%), nMAE (3.07–4.73%), and R² (0.97 to 0.99), especially for short time steps. Compared to conventional and ANN models, the proposed model showed smaller errors, confirming its superior performance. Simultaneously, Moummi et al.⁵⁷ conducted a comparative study using data from the Biskra meteorological station to evaluate the PERRIN DE BRICHAMBAUT and LIU & JORDEN models for calculating daily global radiation on an inclined plane. The study found that both models effectively simulated solar irradiance, with the LIU & JORDEN model aligning better with experimental values at sunrise and sunset and the PERRIN DE BRICHAMBAUT model being more accurate around solar noon. This study serves as a reference for our research due to the similar solar radiation patterns in Biskra and OUED-NECHOU and the use of comparable methodologies. Additionally, other studies^58,59,60 have focused on predicting global solar radiation for inclined surfaces, providing results from various regions.
The following excerpt details an experimental comparison study at the 1.1 MWp photovoltaic power plant in OUED-NECHOU, Ghardaïa. A weather station installed on the rooftop of the technical room at the centre of the plant was used to gather authentic data on solar radiation at a 30° tilt. The overall radiation reaching the Earth’s surface at this angle includes direct, diffuse, and reflected irradiances as depicted in (1).
G_T = Global inclined solar radiation [W/m²].
S = Direct radiation on an inclined plan [W/m²].
D_ciel = Diffuse radiation on an inclined plan [W/m²].
D_sol = Ground reflection radiation on an inclined plan (albedo) [W/m²].
Experimental real-time data was collected using a pyranometer every 4 min, from 06:00 AM to 08:00 PM, over four days in 2016. To estimate the theoretical global irradiance in the OUED-NECHOU region, the PERRIN DE BRICHAMBAUT semi-empirical model was employed, incorporating the linke atmospheric turbidity factor along with atmospheric and astronomical parameters. The equation for global solar irradiance at a 30° tilt was derived using previously obtained geographical data of the region.
Using MATLAB software, the PERRIN DE BRICHAMBAUT model with the Linke atmospheric turbidity factor was applied to simulate the total theoretical inclined irradiance. The results were plotted in Figs. 2, 3, 4, and 5 and compared with experimentally inclined irradiances collected over four days representing each season: January 1^st (Winter), May 1^st (Spring), July 1^st (Summer), and October 1^st (Fall) of 2016.
The graph displays a comparison of inclined irradiances over four days, featuring the experimental data (red curve) and theoretical data (blue curve). It also highlights the absolute error (yallow curve) between these datasets and presents ambient temperature measurements (green curve).
The solar irradiance results show a strong correlation between measured and predicted data on January 1^st (a winter day) and October 1^st (a fall day), particularly at sunrise, sunset, and midday. On January 1^st, the experimental peak solar irradiance was 927.61 W/m², with a predicted value of 865.45 W/m² around midday. On October 1^st, the maximum measured value was 1021.9 W/m², while the estimated value was 980.94 W/m².
On May 1^st (a Spring day), there was a fluctuation in the experimental solar irradiance data compared to the estimated data from 6:00 AM to 12:00 PM. This fluctuation was due to a sharp increase in wind speeds, as shown in Fig. 3, where the highest value recorded by the anemometer sensor reached 8.37 m/s, resulting in instability in the inclined solar radiation during that time. However, from 12:00 PM to 6:00 PM, there was consistency between the experimental and estimated data. The highest value for experimental solar radiation was 1121.6 W/m², while the estimated solar radiation was 1057.3 W/m², both recorded around midday.
On July 1^st (a summer day), we observed consistency between the measured and estimated data from 6:00 AM to 10:00 AM. However, from 10:00 AM to 6:00 PM, disturbances began to appear in the real solar radiation data. These disturbances were due to the changing wind speeds and the presence of clouds, which prevented the passage of solar radiation. The wind speed data on this day was the highest among the four experimental days, with the anemometer sensor recording a maximum of 9.05 m/s. Furthermore, the maximum measured value of solar irradiance was 891.28 W/m², while the estimated value was 1036.2 W/m².
In their study of solar radiance in Biskra, Moummi et al.⁵⁷ concluded that variations in solar radiation data throughout the day are primarily due to climatic disturbances. Similarly, Benbouza Naima et al.⁶¹ demonstrated through images in her study of solar radiation in Batna, Algeria, that several natural factors, including wind and clouds, can significantly affect solar radiative flux, leading to instability in the collected data.
The performance of the semi-empirical model was validated using statistical parameters⁵⁴, including MAE, CC, RMSE, MAPE, and the absolute error curve. These indicators are commonly used in the comparison and assessment of solar radiation models, as highlighted in the literature^{52,53,54,55,56,57,58,59,60,61,62,63,64,65,66}. The results of the statistical analysis over four experimental days are shown in Table 3.
The statistical indicators (MAE, RMSE, CC, and MAPE), evaluated over four days in 2016, demonstrate that the PERRIN DE BRICHAMBAUT semi-empirical model closely matches the actual data.
July 1^st (a summer day) provides the best accuracy for the solar radiance predictions based on the MAE values, with an MAE of 52.2668 W/m². This reflects the smallest average error in the predictions compared to the other days analyzed, indicating superior predictive accuracy. Furthermore, on July 1^st, the model achieved its highest accuracy with the lowest RMSE of 4.2737 W/m², reflecting close alignment between predicted and actual solar radiance values and demonstrating strong performance. The more, the correlation coefficient (CC) of the model is consistently high, exceeding 0.7 over the four measured days, with the highest value of 0.9668 observed on July 1^st. This high CC value indicates a strong correlation between observed and estimated solar radiance in tilt of 30°.These results suggest that the model performs well in correlating observed and estimated values across all days, demonstrating robust predictive capability. The MAPE, which quantifies accuracy as a percentage, shows excellent results with values below 10% for all days. The best performance was observed on July 1^st, with a MAPE of 1.9684%, highlighting the model’s robustness and reliability in estimating inclined solar irradiance.
We can confidently conclude that the PERRIN DE BRICHAMBAUT model provides a good fit and correlation between measured and predicted global solar radiation over four observed days. The model is particularly effective for regions with latitudes below 60°, in line with findings from the Atlas Solaire de l’Algérie⁶⁴. Therefore, this semi-empirical model can be used to predict global inclined solar radiation at a 30° tilt in photovoltaic power plants in OUED-NECHOU, Ghardaïa, even in the absence of a pyranometer instrument.
The power plant, constructed by S.P.E. (Algerian Electricity Production Company), is located approximately 15 km north of Ghardaïa, near the village of OUED-NECHOU. The site spans ten hectares and houses a photovoltaic plant designed to harvest and directly convert sunlight into electricity.
With a nominal power of approximately 1100 kWp, the plant aims to evaluate the performance of various photovoltaic technologies in the southern Algerian environment, where conditions such as high solar radiation and temperature extremes can significantly impact efficiency. This pilot project is divided into eight sub-fields, each containing four photovoltaic modules of different technologies and two types of structures (fixed and motorized). The installation is oriented towards the south (azimuth angle = 0°) and inclined at an angle of 30°.
The Table below represents the central constitution of the photovoltaic power plants at OUED-NECHOU, Ghardaïa distributed as follows:
Figure 8 provides an overview of the PV accessory center at OUED-NECHOU, showcasing the primary photovoltaic technologies present at the site.
Monocrystalline silicon panels (452 kWp).
Polycrystalline silicon panels (452 kWp).
Amorphous silicon (a-Si) panels (100 kWp).
Thin film panels (cadmium telluride CdTe) (100 kWp).
Illustrative Image of the OUED-NECHOU photovoltaic power plant in Ghardaïa, showing its PV subfields inclined at 30° Facing South.
These images were obtained during an experimental study conducted at the center.
This study presents an experimental comparison of four photovoltaic subfields configured as two fixed and two single-axis tracking systems, all inclined at 30°. Each subfield consists of a series-connected array of photovoltaic modules, with each subfield having a capacity of approximately 100 kW. The objective is to evaluate the performance of these photovoltaic technologies, specifically monocrystalline silicon (mc-Si) and polycrystalline silicon (pc-Si), which share identical material compositions but differ in structural configuration. The experiment was conducted over four days under identical meteorological conditions at the OUED-NECHOU site, with specific climatic conditions representative of southern Algeria. Detailed technical parameters are provided below.
Sub-field (1) has a capacity of 105 kWp and features a motorized monocrystalline silicon (mc-Si) structure. The peak power output of each photovoltaic (PV) panel is 250 Wp. This sub-field comprises 420 photovoltaic modules, organized into 21 chains, with each chain consisting of 20 modules.
Sub-field (2): has a capacity of 98.7 kWp with a Motorized polycrystalline silicon structure (pc-Si), and the peak power output of the PV panel is 235 Wp. This sub-field comprises 420 photovoltaic modules, organized into 21 chains, with each chain consisting of 20 modules.
Sub-field (3) has a capacity of 108 kWp with a fixed thin- film structure using Cadmium Telluride (CdTe), and the peak power output of the PV panels 80 Wp .This sub-field comprises 1260 photovoltaic modules, organized into 105 chains, with each chain consisting of 12 modules.
Sub-field (4): has a capacity of 100,116 kWp with a fixed amorphous silicon structure (a-Si), and the peak power output of the PV panel is 103 Wp .This sub-field comprises 972 photovoltaic modules, organized into 54 chains, with each chain consisting of 18 modules.
Sub-field (5) has a capacity of 105 kWp with a Fixed monocrystalline silicon structure (mc-Si), and the peak power output of the PV panel is 250Wp.This sub-field comprises 420 photovoltaic modules, organized into 21 chains, with each chain consisting of 20 modules.
Sub-field (6): has a capacity of 98.7 kWp with a Fixed polycrystalline silicon structure (pc-Si), and the peak power output of the PV panel is 235 Wp. This sub-field comprises 420 photovoltaic modules, organized into 21 chains, with each chain consisting of 20 modules.
Being an experimental site, the Ghardaïa photovoltaic plant was chosen to use four different types of panels and two types of support structures: fixed structures or mobile (motorized tracking systems).
The subfields containing either fixed structures or automated tracking systems are discripted above Either the fixed structures or the motorized structures will be installed on the ground through concrete blocks. The structures will be made of galvanized steel, and sized in accordance with site conditions. The fixed structures will be oriented towards the south with a tilt angle of 30°, to optimize the sunshine on the panels see Fig. 9.
Fixed structure of the photovoltaic system in the OUED-NECHO subfields for monocrystalline (mc-Si) and polycrystalline (pc-Si) technologies.
The tracking systems will be of the single-axis type, with the axis oriented in the east–west direction. Throughout the day, the tracker follows the sun’s movement from sunrise to sunset, using (azimuthal tracking) from east to west . The panels installed on the tracker will be tilted at a 30° angle to enhance sunlight capture. This configuration maximizes the angle of incidence of sunlight on the panels throughout the day, thereby improving the efficiency and power output of the photovoltaic system compared to fixed-tilt systems. Additional details about the motorized structures are shown in Fig. 10.
Single-axis tracking structure of the photovoltaic system in the OUED-NECHO subfields for monocrystalline (mc-Si) and polycrystalline (pc-Si) technologies.
Each tracker is moved by an electric motor located on the system and powered by a low voltage (LV) panel of the power plant Fig. 11.
Motorized tracking system for the PV subfields (SLAVE).
The movement of the tracking systems is synchronized by a proprietary control system (PLC). Tracking systems will need to return the modules to horizontal for high wind speed.
The functional operation of the single-axis tracking system, as illustrated in Figs. 10 and 11, is described as follows:
During operation, the tracking mechanism followed a stepped movement protocol: each drive chain was activated for approximately 5 s, followed by a 10-min rest period, in sequential order across 21 chains. This gradual motion minimized actuator wear and reduced energy consumption. Position control relied on mechanical limit switches and predefined end stops, as the system lacked high-resolution encoders due to its legacy design. This stepped strategy provided near-continuous sun-following while significantly reducing motor duty cycles. The mechanical drive employs a toothed gearing system composed of an electric motor and meshing gear teeth.
Data collection was conducted using the central PV monitoring system, which logged DC output power, tracker motion events, and meteorological variables at 4-min intervals from sunrise to sunset. Pyranometers and temperature sensors were visually inspected and zero-adjusted according to manufacturer guidelines prior to the measurement campaign. Sensor readings were periodically cross-checked, and tracker alignment was verified at predefined timestamps to ensure accuracy and reliability of measurements.
The electrical characteristics of the PV modules at standard testing conditions (1000 W/m², 25 °C, AM1.5) are detailed in Table 4. Both monocrystalline and polycrystalline technologies adhere to the same manufacturer’s specifications for tracking and fixed systems.
In this section, we will evaluate four critical aspects of the performance of photovoltaic (PV) subfields: (I) Output Power, (II) Environmental Factors Influencing Performance, (III) Augmentation Percentage, and (IV) Daily Energy Yield. The primary objective of this assessment is to identify which PV subfield demonstrates the highest performance and is the most suitable for installation in regions with desert climatic conditions, such as the OUED-NECHOU region in Ghardaïa City.
To evaluate photovoltaic module performance, a simulation approach was conducted by Constance Kalu et al.⁴⁷. Using PVsyst version 5.21 and NASA meteorological data along with hypothetical load demand, the study compares polycrystalline, monocrystalline, and thin-film PV technologies. It finds that thin-film PV technology, despite its low array loss, low unit cost of energy, and favorable performance metrics, requires a larger installation area. In contrast, polycrystalline PV technology, with higher efficiency and smaller space requirements, is deemed more suitable for the specific site due to its superior efficiency and compact space needs. Furthermore, Allouhi et al.⁴⁵ assessed the performance, economic feasibility, and environmental impact of 2 kWp grid-connected PV systems (Poly-Si and Mono-Si) installed at the High School of Technology, Meknes, Morocco. The two PV fields are oriented south at a fixed tilt angle of 30°. Using METEONORM data and PVSYST simulations, the study found Poly-Si modules slightly outperform Mono-Si, with a higher annual average daily final yield. The Meknes systems perform better than those in Greece, Ireland, India, South Africa, and the UAE. Economically, Poly-Si has a lower levelized cost of electricity ($0.073/kWh) and shorter payback time (11.10 years) compared to Mono-Si ($0.082/kWh and 12.69 years). The systems also offer significant environmental benefits, reducing CO2 emissions by about 5.01 tons annually. The International Electrotechnical Commission (IEC) recommends several parameters for assessing PV power plant performance, as outlined in IEC-61724 standards. Key parameters include the final yield (Yf), reference yield (Yr), performance ratio (PR), and capacity factor (CF) Cubukcu & Gumus⁶⁵. Pirzadi & Ghadimi⁶⁶. Veerendra Kumar et al.⁶⁷. Ismail Bendaas et al.⁶⁸. Irfan Jamil et al.^{54,60,61,62,63,64,65,69}. These indicators are crucial for evaluating the efficiency and profitability of various PV power plants under different climatic conditions and for detecting potential issues or failures. Building on this. El Mehdi Karami et al.⁷⁰ evaluated the performance of grid-connected PV systems with monocrystalline, polycrystalline, and amorphous silicon modules in Casablanca, using 2016 data and PVsyst simulations. They assessed performance parameters such as annual energy generation, final yield, reference yield, performance ratio, and capacity factor. Results indicated that simulations were accurate for energy production and irradiation but less accurate for ambient temperature. Performance ratios were 76.94% for p-si, 78.02% for c-si, and 67.28% for a-si, with final yields of 4.61, 4.68, and 4.02 kWh/kWp/day, respectively. The study confirms PVsyst’s reliability but suggests using on-site temperature measurements for better simulation accuracy.
Assessing solar panel performance by analyzing output power, a critical electrical parameter, is essential for comparative studies, especially when considering the specific meteorological conditions of a given location. El Mehdi Karami et al.⁷⁰ conducted additional research to evaluate the performance of different solar panel technologies. They assessed the DC power output from the modules and the AC power from the inverters using real-time measurements under various weather conditions clear, cloudy, and rainy. Additionally, Layachi Zaghba et al.⁷¹ conducted an experimental study on an 11.28 kWp grid-connected solar system with sun tracking over one year at the Applied Research Unit of Renewable Energy in Ghardaia, Algeria. The study combines simulation data from PVSYST with experimental results and features three 3.76 kWp solar tracker configurations: fixed-axis, one-axis, and dual-axis. In a specific section, it compares the power output of single-axis and dual-axis trackers with fixed-axis systems under varying weather conditions, including clear and cloudy skies. Arechkik Ameur et al.⁷² aimed to analyze and compare various indices for evaluating the performance of three grid-connected photovoltaic technologies (a-Si, pc-Si, and mc-Si) in Ifrane, Morocco, et al. Akhawayn University. The study examines systems generating 2 kWp each, installed facing south on a flat surface, tilted at 32°, with zero azimuth. It evaluates AC power output under sunny and snowy conditions, considering the impact of temperature on power output.
Two different crystalline silicon photovoltaic technologies, monocrystalline silicon (mc-Si) and polycrystalline silicon (pc-Si), were evaluated using two types of support structures: fixed-axis and single-axis, both with a 30° tilt. Each PV subfield consisted of identical 100 kWp systems. Data were collected every 4 min in real-time through field measurements, as illustrated in Figs. 12, 13, 14, and 15. A comparative analysis was conducted. On the peak output power and long-term daily power generation for January 1^st, May 1^st, July 1^st, and October 1^st, representing the four seasons.
Comparison of output power (kW) between fixed and single-axis PV subfields for mc-Si and pc-Si on January 1^st, 2016. A winter day .
Comparison of output power (kW) between fixed and single-axis PV subfields for mc-Si and pc-Si on May 1^st, 2016. A spring day .
Comparison of output power (kW) between fixed and single-axis PV subfields for mc-Si and pc-Si on July 1^st, 2016. A summer day .
Comparison of output power (kW) between fixed and single-axis PV subfields for mc-Si and pc-Si on October 1^st, 2016. A fall day .
After confirming the accuracy of the PV subfields’ real performance data. Figure 12 shows the power output of the fixed-axis and one-axis mc-Si and pc-Si subfields on a winter’s day in January 1^st, 2016. Around 12:58 PM, the fixed mc-Si subfield reached its peak of 82.31 kW, the highest output of the day. Earlier, at 10:37 AM, the motorized mc-Si subfield produced 75.10 kW. Past midday the fixed pc-Si subfield generated 73.98 kW at 12:57 PM, while the motorized pc-Si recorded the lowest output of 73 kW at 10:50 AM.
The findings from the four PV subfields on May 1^st, 2016, a spring day, are displayed in Fig. 13. Showing the maximum power output recorded during the four-day pilot study. At 12:23 PM, the fixed mc-Si subfield achieved the highest power output ever recorded, approaching 95.67 kW.This was followed by the motorized mc-Si subfield, which produced 88.35 kW at 12:20 PM. At the same time, the fixed pc-Si subfield produced 84.06 kW, while the motorized pc-Si subfield recorded the lowest output of 83.01 kW at 14:40 PM.
Figure 14 illustrates the comparison of output power curves from four subfields one -axis and fixed-axis mc-Si and pc-Si using real data from July 1^st, a summer day. The experimental results on this day differed from those of the previous day. The one-axis mc-Si subfield yielded the highest power output on this day, producing 86.38 kW at 12:56 PM. This was followed by the fixed mc-Si subfield, which generated 83.84 kW at 12:46 PM. The motorized pc-Si subfield produced 76.84 kW at 13:28 PM, while the fixed pc-Si subfield achieved 71.12 kW.
Figure 15 presents experimental real data on output power for fixed-axis and one-axis PV subfields from October 1^st, 2016, covering a full day. The curves reveal that the fixed-axis mc-Si subfield yielded the highest output power compared to other subfields, achieving 88.00 kW at 12:56 PM. Following this, the one-axis mc-Si subfield delivered 78.79 kW at 13:05 PM. Additionally, the performance comparison between the fixed and single-axis pc-Si subfields shows a relatively close peak output, with the fixed pc-Si subfield achieving 76.88 kW and the single-axis pc-Si subfield reaching 73.06 kW at 10:50 AM.
When comparing the DC output power performance of four conventional PV subfields in this section, the results from four experimental days indicate that on each of these days, the power output of the solar panels was monitored from sunrise to sunset, between 06:00 AM and 19:52 PM. Among the subfields, the fixed monocrystalline (mc-Si) consistently generated the highest output power, with a peak value of 95.67 kWp recorded on May 1^st, close to the subfield’s optimal capacity. Additionally, on the same day, the single-axis monocrystalline (mc-Si) subfield demonstrated a peak output power of 88.35 kWp.
Notably, the single-axis solar tracker consistently increased the amount of power generated throughout all experimental days, from sunrise to sunset, by capturing more solar radiation compared to a fixed module. This effect was particularly evident on January 1^st, May 1^st, and July 1^st. As a result, by implementing single-axis tracking systems in our mc-Si and pc-Si subfields, the PV panels were able to continuously track the sun. These systems ensure that the panels remain optimally aligned with the sun throughout the day and across the year, maximizing the exposure of the panel’s surface. This alignment leads to increased conversion efficiency and, consequently, higher electricity generation (output power). Additionally, tracking systems optimize land area usage for electricity production compared to non-tracking systems, making them a more efficient choice. This finding is consistent with those obtained by many authors who have studied solar tracking systems. Hafez et al.⁷³ introduced an innovative solar single-axis tracking system powered by a Stirling engine, which was used to evaluate the performance of solar panels in Giza, Egypt. The East–West axis system achieved higher output power than the fixed system. Research carried out by Layali Abu Hussein et al.⁷⁴ in Amman, Jordan, looked into the performance improvement of standard fixed photovoltaic (PV) solar systems by using single and dual-axis sun tracking mechanisms. They compared these systems to concentrated photovoltaic (CPV) systems, which inherently use tracking systems. The study included an experimental analysis, characterization, and performance comparison of four mounting types of standard PV systems. The PV panels were installed using either a fixed mount, single-axis (East–West tracking), single-axis (North–South tracking), or dual-axis tracking. The study’s findings confirmed that electrical power generation on tracking surfaces was significantly higher than on a fixed surface. Additionally, the study demonstrated that both East–West and North–South tracking systems produced more power compared to a fixed surface inclined at 26° to the south.
Climatic, environmental, and operational conditions, along with geographical locations, play a crucial role in the energy yield of photovoltaic (PV) systems. This concept has driven research focused on quantifying and modeling the output power of PV systems under diverse conditions. Researchers globally aim to understand better how these parameters affect PV system performance. According to Elkholy et al.⁷⁵, reduced solar irradiation significantly influences the energy quality produced by photovoltaic systems.Dabou et al.⁷⁶, conducted a study examining the impact of climatic conditions on the performance of grid-connected photovoltaic systems. The findings indicate that performance is influenced on cloudy and sandy days due to the rapid and successive changes in cloud cover and sand exposure, which affect both the energy output and the stability of the photovoltaic system. In their 2014 study, Panagea et al.⁷⁷ discovered a clear inverse link between PV power and temperature in Greece. They also observed that as irradiance intensity rises, so does PV power. As reported by Schwingshackl et al.⁷⁸ and Kaplani and Kaplanis⁷⁹, wind speed significantly enhances PV performance by cooling the PV surfaces, which in turn reduces the parallel resistance within the PV circuit model. Humidity decreases PV output by diminishing the amount of solar irradiance received. Nevertheless, when combined with wind speed, humidity significantly contributes to cooling PV surfaces, thereby enhancing PV efficiency in hot climates Zainuddin et al.⁸⁰.
Currently, no published studies provide experimental results on the performance of photovoltaic systems and their interaction with environmental factors in the OUED-NECHOU region, Ghardaïa. This section presents a comparative analysis of the influence of meteorological parameters on photovoltaic subfield performance based on experimental data. The study evaluates the effects of solar irradiance at a 30° tilt, cell irradiation at the same angle, ambient temperature, cell temperature, relative humidity (Fig. 2), and wind speed (Fig. 3) on the DC power output. Furthermore, the performance of both fixed and motorized (single-axis) subfields is analyzed to determine which technology is more effective under these environmental conditions. Real-time meteorological data was collected using sensors installed at a weather station (Table 1) on the roof of the control room, recorded at four-minute intervals on January 1^st, May 1^st, July 1^st, and October 1^st each representing a different season. The data was displayed and analyzed, as shown in Figs. 2, 3, 16, and 17.
Daily experimental data of average ambient temperature (°C) and module temperature (°C) over four days, each corresponding to a different season.
Daily experimental data of average inclined solar irradiance (W/m²) and calibrated cell radiation (W/m²) for four subfields over four days, measured at a 30° tilt angle.
Figure 16 compares experimental data from four days, including ambient temperature recorded by a thermo-hygrometer installed at the weather station and PV module temperature from both fixed and motorized technologies, measured by cell sensors installed in the subfields. Data analysis revealed that ambient temperatures consistently exceeded the temperatures recorded by the PV cell sensors throughout the four experimental days. PV module temperatures also increased with rising ambient temperatures, with the most significant effect observed on July 1^st.
The fixed mc-Si technology reached its peak panel surface temperature of 33.16 °C on July 1^st and its lowest of 23.02 °C on May 1^st, while the fixed pc-Si PV technology recorded its highest at 32.19 °C on May 1st and its lowest at 21.21 °C on January 1^st. These distinct temperature changes vividly illustrate the seasonal performance variations of these PV technologies. On July 1^st, mc-Si and pc-Si one-axis panels recorded their maximum average temperatures of 27.88 °C and 31.39 °C, respectively, while on January 1^st, they had their minimum averages at 18.49 °C and 21.92 °C.
Figure 17 showcases an experimental comparison of inclined solar irradiance (W/m²) recorded by a pyranometer and measured by calibrated cells, both positioned at a 30° tilt angle over four days representing different seasons.
Significant emphasis was placed on the clear and qualitative response of the subfields to different levels of solar radiation. The motorized mc-Si and pc-Si subfields outperformed the fixed subfields and the pyranometer in capturing solar radiation.
On July 1^st, a summer day, the monocrystalline silicon (mc-Si) technology recorded a peak average solar irradiance of 782.51 W/m², the highest observed during the study. In contrast, the lowest value, 504.11 W/m², was recorded on October 1^st, a fall day. On January 1^st, a winter day, the irradiance was 730.94 W/m², while on May 1^st, a spring day, it was 508.41 W/m². The motorized pc-Si subfield also achieved significant irradiance values, with a maximum average of 627.21 W/m² on July 1^st. On May 1^st, it recorded 576.68 W/m². During winter (January 1^st) and fall (October 1^st), the irradiance values were 502.77 W/m² and 449.67 W/m², respectively.
On May 1^st, the pyranometer recorded a maximum average solar irradiance of 651.16 W/m². The fixed mc-Si sub-field recorded an average irradiance of 560.58 W/m², which is 90.58 W/m² lower than the pyranometer’s measurement. The fixed pc-Si subfield recorded a maximum irradiance of 550.58 W/m², showing a difference of 100.58 W/m² from the pyranometer’s reading. In October, the pyranometer recorded the lowest tilted solar irradiance values in this study, with a minimum of 442.03 W/m². The fixed mc-Si subfield measured 428.61 W/m², 13.42 W/m² lower than the pyranometer’s reading, while the fixed pc-Si subfield recorded 422.61 W/m², 19.42 W/m² below the pyranometer’s measurement.
These measurements illustrate the variability in irradiance captured by different PV technologies, highlighting the pyranometer’s role as a benchmark for evaluating the performance of photovoltaic subfields in capturing solar radiation.
The experimental results indicate that one-axis solar subfields consistently generate more power from sunrise to sunset compared to fixed subfields. This increased power production was particularly evident on January 1^st, May 1^st, and July 1^st. The east–west alignment of single-axis panels optimizes solar energy absorption by optimizing the polarization angle of incoming solar radiation.
Natural factors clearly influence this variation in power production. Extensive studies have proven this, including those by Karami et al.²⁷. Al-Otaibi et al.⁴⁹, and Moafaq et al.⁸¹. Layali Abu Hussein et al.⁷⁴. At the OUED-NECHOU station, the tilt angle of the solar panels plays a crucial role in determining photovoltaic subfield efficiency. A well-adjusted tilt that aligns closely with the region’s optimal angle improves solar energy absorption and enhances power generation. Observations on May 1st and July 1^st revealed that single-axis subfields benefited the most from increased solar irradiance, resulting in notable power gains⁷⁴. On July 1^st, the motorized panels recorded peak solar radiation values of 782.51 W/m² for mc-Si and 625.51 W/m² for pc-Si, highlighting their ability to maximize power generation compared to fixed panels. During the experimental study, the average temperatures of the photovoltaic (PV) technologies remained close to the optimal Standard Test Condition (STC) of 25 °C, occasionally exceeding this temperature. Notably, on July 1^st, higher temperatures contributed to significant DC power generation, indicating favorable conditions for efficient operation. Despite the increase in temperature, power output rose, with the single-axis subfields achieving more significant gains than the fixed subfields. It suggests that elevated temperatures did not hinder performance but enhanced productivity. On July 1^st, conditions were particularly advantageous for both fixed and motorized panels, leading to higher energy yields. A similar trend was observed on May 1^st, where rising temperatures also correlated with increased power output. The recorded average temperatures on these days remained within the optimal range for solar panel performance. High temperatures negatively affect the performance of solar panels, as they reduce their efficiency and power output. The evidence for this previous study conducted in Southeast China by Du et al.⁸² showed that temperatures above 60 °C significantly reduce panel power output while lowering the temperature below this threshold increases efficiency and power generation. The panels operated near their optimal capacity since such extreme temperatures were not observed in our experimental study. Since rising temperatures adversely affect the performance of solar panels, finding practical solutions to alleviate this impact is crucial. Researchers such as Mohamed R. Gomaa et al.⁴⁴, their study experimentally evaluated two cost-effective cooling methods to enhance PV system performance: direct active cooling using water and passive cooling with fins. A non-cooled PV module was used as a reference for comparison. The findings showed that the water cooling method reduced the module surface temperature to 38 °C, while the fin cooling method brought it down to 55 °C, compared to 58 °C for the non-cooled module. These cooling techniques enhanced energy performance, resulting in a 10.2% increase in daily harvested energy for the water-cooled module and a 7% increase for the fin-cooled module. Additionally, the performance ratio improved to 84% with water cooling and 81% with fins, while the non-cooled module had a performance ratio of 77%.
Furthermore, wind speed and humidity significantly impact the efficiency of photovoltaic subfields. During the experimental period, we observed that higher wind speeds and lower humidity levels improved solar panels output. Increased airflow effectively reduced localized humidity on May 1^st and July 1^st by promoting continuous air movement over the panels. It led to increased power generation. Additionally, motorized subfields outperformed fixed subfields due to the cooling effect of wind, lower atmospheric moisture, and better solar absorption, resulting in consistently superior performance. Our experimental analysis confirmed an inverse relationship between wind speed and relative humidity: as wind speed increased, humidity levels decreased, further supporting these findings. Water condensation on solar panels can decrease their efficiency by causing moisture build-up. To address this issue, we optimize the tilt angle in our subfields, where photovoltaic panels are installed at a fixed tilt of 30° which allows water droplets to run off rather than accumulate, thus minimizing prolonged moisture exposure. Additionally, natural airflow in well-ventilated areas enhances this effect. On May 1^st and July 1^st, increased airflow effectively reduced localized humidity by promoting continuous air movement over the panels. This led to higher power gains for the single-axis tracking system and improved overall power generation.
These observations reinforce the idea that a single meteorological factor does not determine a photovoltaic system’s ability to convert solar radiation into electrical energy; rather, it is the combined influence of irradiance, temperature, wind speed, humidity, and panel orientation. Under favorable conditions- high irradiance, moderate temperatures, enhanced airflow, and reduced surface moisture—the panels can absorb a greater portion of incoming solar energy, resulting in higher conversion efficiency and improved power output. In particular, single-axis tracking systems show a stronger response to these favorable environmental conditions, as their continuous orientation toward the sun maximizes capture of direct beam radiation while also enhancing natural cooling through increased exposure to wind. This synergistic interaction among optimal tilt alignment, improved heat dissipation, reduced moisture accumulation, and maximum irradiance collection significantly contributes to the superior performance of single-axis tracking subfields compared to fixed systems in desert environments such as OUED-NECHOU.
In regions like OUED-NECHOU, which are generally hot and dry but can occasionally experience localized humidity, additional measures can further optimize PV performance. Installing small fans or passive ventilation systems activated by humidity sensors can help remove water droplets from the panel surface while keeping energy consumption minimal. This approach ensures efficient panel operation without compromising energy production, particularly for single-axis systems designed to capture maximum solar radiation. By combining these environmental insights with practical mitigation strategies, PV systems can maintain higher efficiency and more stable power output under varying desert conditions.
The concept of “Augmentation Percentage” in the realm of renewable energy, particularly photovoltaic technologies, denotes the relative enhancement in the performance of a specific technology or system compared to a reference or baseline technology. This metric is determined by calculating the percentage increase or decrease in a particular performance indicator (e.g., power output or efficiency) of the new or alternative technology relative to the baseline⁴⁶.
Baseline Technology: This term refers to the standard or reference photovoltaic (PV) technology or system used as a starting point for comparison. It signifies the most prevalent, widely used, or preferred technology in your study.
The percentage of augmentation would be calculated as follows:
AP: Augmentation percentage (%).
P_baseline: Mean output power (KW) of the baseline (reference) technology or subfield.
P_new : Mean output power (KW)of the new technology or subfield.
The performance improvement of two single-axis tracking sub-fields was evaluated in comparison to two fixed photovoltaic sub-fields during a four-day experimental period in 2016, with each day representing a different season. Monocrystalline (mc-Si) and polycrystalline (pc-Si) silicon technologies were used. Mean output power was measured for both subfield types, and the percentage of augmentation was calculated to quantify the performance gains.
Data from January 1^st, 2016, shown in Fig. 18. Illustrates the increase in mean output power (in kW) for single-axis tracking systems compared to fixed systems for mc-Si and pc-Si sub-fields. The single-axis tracking sub-fields served as baseline technologies for comparison. The mc-Si single-axis tracking system achieved a mean output power of 57.060 kW, representing a 3.263% increase over the fixed sub-field output of 55.198 kW. Similarly, the pc-Si single-axis tracking system generated 55.318 kW, resulting in an 11.849% increase compared to the fixed sub-field output of 48.763 kW.
Percentage increase in mean output power for fixed and single-axis tracking subfields (mc-Si, pc-Si) on January 1^st, 2016 (winter day).
In Fig. 19 the results of an experiment conducted on May 1^st, 2016 are presented. The experiment aimed to compare the mean output power of fixed and single-axis tracking systems for mc-Si and pc-Si sub-fields during the Spring .The results show that the single-axis tracking subfield, designated as baseline I for mc-Si and baseline II for pc-Si, significantly outperformed the fixed systems. Specifically, the mc-Si single-axis tracking system achieved a mean output power of 57.710 kW, representing a 9.979% increase over the fixed system’s output of 51.451 kW. Similarly, the pc-Si single-axis tracking system generated 56.940 kW, resulting in a 20.226% increase compared to the fixed system’s output of 45.423 kW.
Percentage increase in mean output power for fixed and single-axis tracking subfields (mc-Si, pc-Si) on May 1^st, 2016 (spring day).
Figure 20 presents data on the percentage increase in mean output power (in kW) for single-axis tracking and fixed systems using mc-Si and pc-Si subfields on July 1^st, a summer day. The mc-Si single-axis tracking system, considered as Baseline I, achieved a mean output power of 60.470 kW, representing a 19.221% increase over the fixed system’s output of 48.847 kW. Similarly, the pc-Si single-axis tracking system, established as Baseline II, generated 54.864 kW, resulting in a 21.444% increase compared to the fixed system’s output of 42.550 kW.
Percentage increase in mean output power for fixed and single-axis tracking subfields (mc-Si, pc-Si) on July 1^st, 2016 (spring Day).
On October 1^st, on a fall day, Fig. 21 depicts the percentage increase in average output power (in kW) for single-axis tracking and fixed systems using mc-Si and pc-Si subfields. The single-axis tracking systems are referred to as Baseline I for the mc-Si sub-field and Baseline II for the pc-Si sub-field. The mc-Si single-axis tracking system achieved a mean output power of 48.600 kW, representing a 9.362% increase over the fixed system’s output of 44.050 kW. Similarly, the pc-Si single-axis tracking system generated 45.134 kW, resulting in an 11.791% increase compared to the fixed system’s output of 39.812 kW.
Percentage increase in mean output power for fixed and single-axis tracking subfields (mc-Si, pc-Si) on October 1^st, 2016 (spring day).
The empirical data clearly demonstrates that single-axis tracking systems lead to a substantial increase in the daily average power output (kW) for both mc-Si and pc-Si subfields compared to fixed subfields. This underscores the crucial role of tracking mechanisms in enhancing subfield performance, especially in regions with high solar radiation, diverse sun paths, and favorable weather conditions.
All photovoltaic (PV) subfields have the same power capacity, with a rated instantaneous output of 100 kW. Figure 22 displays the results of a comparative experimental analysis of daily energy production between fixed and single-axis tracking subfields ,conducted over four days, each representing a different season. This study investigates how solar irradiance influences energy variations, emphasizing its role in enhancing productivity in photovoltaic subfields, particularly when utilizing a mechanical tracking system. To ensure accuracy and reliability, energy generation data was recorded at four-minute intervals throughout the daily measurement period.
Comparison of daily energy generation in fixed and single-axis tracking PV subfields across four experimental days.
On January 1^st, in winter, the single-axis mc-Si subfield recorded the highest energy output at 547.73 kWh/day, followed by the single-axis pc-Si system, which yielded 531.05 kWh/day. In comparison, the fixed mc-Si system generated 529.92 kWh/day, while the fixed pc-Si subfield produced the least energy at 468.14 kWh/day. The overall low energy production observed on January 1^st can be attributed to the weak solar radiation and the shorter duration of daylight typical of winter.
The data recorded on May 1^st highlights the seasonal effects on energy production. During the spring season, energy production saw a significant increase due to the transitional seasonal conditions. The mc-Si single-axis system achieved a peak output of 750.24 kWh/day, while the pc-Si single-axis subfield generated 646.85 kWh/day. The fixed mc-Si configuration also performed well, producing 671.50 kWh/day, whereas the fixed pc-Si system generated 590.50 kWh/day.
The highest recorded energy output was observed on July 1^st, during the summer season. The mc-Si single-axis subfield achieved its peak generation, producing 787.94 kWh/day, while the pc-Si single-axis system closely followed with 715.17 kWh/day. Among the fixed systems, the mc-Si subfield generated 636.15 kWh/day, whereas the pc-Si fixed system recorded the lowest output for this period at 553.43 kWh/day. This notable increase in performance is attributed to extended daylight hours and higher irradiance levels during the summer.
As fall began on October 1^st, a decline in energy generation was observed. The mc-Si single-axis subfield led the performance with an output of 550.77 kWh/day, followed by the pc-Si single-axis system, which generated 511.52 kWh/day. The fixed mc-Si system produced 498.17 kWh/day, while the fixed pc-Si subfield had the lowest recorded energy output for this period, generating only 451.21 kWh/day.
The superior energy yield of motorized subfields is attributed to their ability to continuously track the sun’s position throughout the day, maximizing the capture of solar irradiance. This dynamic orientation reduces angle losses and ensures that the photovoltaic (PV) modules receive optimal sunlight exposure, particularly during the early morning and late afternoon when fixed systems tend to exhibit lower efficiency. Additionally, optimizing the mechanical tilt of solar panels enhances direct irradiance absorption, thereby increasing energy generation. These findings highlighted the benefits of single-axis tracking technology, particularly in regions with high solar potential, where seasonal variations can greatly affect photovoltaic efficiency.
Despite its valuable contributions to understanding the performance of fixed and single-axis PV systems under real desert conditions, this study has certain limitations. The experimental analysis was limited to four days representing different seasons, providing representative seasonal insights but not capturing long-term year-round variability or extreme meteorological conditions. The results are site-specific to the OUED-NECHOU region in Ghardaïa, characterized by Saharan climatic conditions with high solar irradiance and notable variations in ambient temperature, wind intensity, and humidity; therefore, the findings may not be directly generalizable to regions with different environmental or irradiance profiles. Furthermore, the study focused exclusively on crystalline silicon technologies—monocrystalliene (mc-Si) and polycrystalline (pc-Si)—without considering other photovoltaic technologies, such as thin-film or bifacial modules, which may behave differently under similar conditions. Future research should extend the monitoring period, include additional PV technologies, and integrate economic and degradation analyses to provide a more comprehensive understanding of PV system performance and sustainability. These aspects will be addressed in forthcoming studies to strengthen the findings further.
This study systematically compared the performance of four photovoltaic (PV) subfields monocrystalline (mc-Si) and polycrystalline (pc-Si) -in fixed and single-axis tracking (East–West) configurations, each with a 30° tilt and 100 kWp capacity. Performance was analyzed over four days representing different seasons under varying meteorological conditions to determine the most effective configuration.
The semi-empirical PERRIN DE BRICHAMBAUT model was used to forecast solar flux on the 30° inclined surface in real time. Statistical analysis demonstrated high model accuracy, with correlation coefficients (CC) between 0.8273–0.9668, RMSE of 4.27–7.72 W/m², MAE of 52.27–65.94 W/m², and MAPE of 1.97–8.87%. The small absolute error across most days confirmed that the model closely predicted actual measurements, indicating it can reliably estimate inclined solar irradiance in OUED-NECHOU and similar Saharan regions even in the absence of a meteorological station.
Daily output power data showed that May 1^st recorded the highest peak outputs. The fixed mc-Si system reached 95.57 kW, followed by the mc-Si single-axis system at 88.35 kW , the fixed pc-Si subfield at 84.06 kW, and the pc-Si single-axis system at 83.01 kW. Average daily production revealed peak outputs of 60.47 kW (single-axis mc-Si, July 1^st ), 55.20 kW (fixed mc-Si, January 1^st ), and 56.94 kW (single-axis pc-Si, May 1^st ), with 48.76 kW for the same subfield on January 1^st.
The analysis of four days of experimental data revealed a strong correlation between meteorological factors—including solar irradiance, cell and ambient temperatures, wind speed, and relative humidity—and PV power output. Higher irradiance levels directly increased power generation, especially in crystalline silicon modules, which showed strong responsiveness to irradiance variations. For instance, the mc-Si single-axis system reached irradiance peaks of 782.51 W/m² on July 1^st and 730 W/m² on May 1^st, resulting in corresponding rises in power output. The superior performance of the single-axis system is attributed to its motorized tracking mechanism, which continuously aligns the panels with the sun’s east–west movement, ensuring optimal solar capture.
PV performance was also influenced by temperature: efficiency remained high within the optimal range around 25 °C, while excessive heat slightly reduced output voltage. On July 1^st, the highest average temperature coincided with the greatest power gain in single-axis systems, confirming that temperature played a favorable role under these conditions. Moreover, higher wind speeds and lower humidity on May 1st and July 1st enhanced power generation by cooling the cells, whereas low wind and high humidity on January 1st and October 1st reduced performance due to cloud cover and water condensation on panel surfaces that limited irradiance absorption.
Tracking systems consistently enhanced photovoltaic performance compared to fixed installations. Both monocrystalline (mc-Si) and polycrystalline (pc-Si) single-axis subfields delivered higher power outputs across all experimental days, with the greatest gains observed on July 1^st and May 1^st. On these dates, the mc-Si tracker generated 19.22% and 9.98% more power gain than its fixed counterpart, while the pc-Si tracker produced 21.44% and 20.23% more than fixed pc-Si subfield, respectively. The lowest gains occurred on January 1^st for mc-Si (3.263%) and on October 1^st for pc-Si (11.791%).
The analysis confirmed the superior performance of single-axis tracking systems in energy production. On May 1^st, they generated 750.24 kWh/day for mc-Si and 646.85 kWh/day for pc-Si, while on July 1st, the outputs reached 787.94 kWh/day and 715.17 kWh/day, respectively. In contrast, fixed systems produced lower values of 671.50 kWh/day and 590.50 kWh/day on May 1^st, and 636.15 kWh/day and 553.43 kWh/day on July 1^st. These results highlight the effectiveness of tracking mechanisms in maximizing solar energy capture. Overall, the single-axis polycrystalline subfield exhibited slightly higher power gains than the monocrystalline one, while the mc-Si single-axis configuration showed the best overall efficiency in energy production. Therefore, implementing polycrystalline technology is recommended for the OUED-NECHOU region and similar Saharan environments due to its strong adaptability to local conditions.
Future improvements should focus on optimizing tilt angles and integrating adaptive control algorithms to enhance energy yield. Regular monitoring of photovoltaic (PV) panels is essential, particularly for single-axis tracking systems in dust-prone regions such as OUED-NECHOU. Beyond these practical enhancements, broader research should explore the development of climate-resilient, intelligent tracking systems suited to harsh desert environments. Kumba et al.¹⁸ provide a comprehensive review of solar tracking systems, discussing key operational and environmental challenges as well as future research directions, including optimization of mechanical architectures and adaptive control strategies. Likewise, Ponce-Jara et al.²⁰ demonstrated that single-axis tracking can substantially increase daily and long-term energy yield, although performance is influenced by local irradiance and climatic conditions.
Consistent with these findings, our experimental results in OUED-NECHOU confirmed that motorized single-axis tracking systems significantly enhance daily power production and energy generation across all seasons. Therefore, future studies should incorporate adaptive intelligent controllers, real-time environmental monitoring, predictive maintenance strategies, and alternative performance indicators to further optimize system efficiency, resilience, and durability under desert climatic conditions.
In addition to performance improvements, future research should evaluate the economic viability of single-axis tracking systems in the regional context. Recent techno-economic analyses Gol & Ščasný⁸³ show that one-axis trackers produce 20–30% more energy than fixed systems and achieve a lower LCOE. Demirdelen et al.⁸⁴ demonstrated that in Mediterranean climates, tracking systems offer significantly faster payback compared to fixed installations. Furthermore, Ayadi et al.⁸⁵ reported that in desert conditions, bifacial 1-axis tracking configurations can achieve a competitive LCOE of as low as ~ 2.45 ¢/kWh under favorable circumstances. Building on these insights, we plan to conduct a long-term, region-specific techno-economic assessment for OUED-NECHOU, including LCOE modeling, life-cycle costing, and maintenance cost projections. By integrating both performance and economic perspectives, future research will contribute to designing optimized, reliable, and cost-effective PV systems tailored to challenging desert environments like OUED-NECHOU.
The datasets used and/or analyzed during the current study are available from the corresponding author upon reasonable request.
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The authors would like to acknowledge the Deanship of Graduate Studies and Scientific Research, Taif University for funding this work.
This work is funded and supported by the Deanship of Graduate Studies and Scientific Research, Taif University.
Laboratory of Electrical Engineering (LAGE), Department of Electrical Engineering, University of Kasdi Merbah Ouargla, 30000, Ouargla, Algeria
Bouramdane Abderraouf, Louazene Mohammed Lakhdar, Benmir Abdelkader & Larouci Benyekhlef
Department of Electrical Engineering, University Kasdi Merbah Ouargla, Ouargla, Algeria
Larouci Benyekhlef
Smart Grid Development Laboratory, ESGEEO, Oran, Algeria
Larouci Benyekhlef
Department of Electrical Engineering, College of Engineering, Taif University, 21944, Taif, Saudi Arabia
Salah K. Elsayed & Abdulrahman Babqi
Department of Electrical and Computer Engineering, Faculty of Technology, Debre Markos University, P. BOX 269, Debre Markos, Ethiopia
Daniel Limenew Meheretie
Electrical Department, Faculty of Technology and Education, Suez University, Suez, 43527, Egypt
Walid S. E. Abdellatif
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Bouramdane Abderraouf, Louazene Mohammed Lakhdar, Benmir Abdelkader, Larouci Benyekhlef: Conceptualization, Methodology, Software, Visualization, Investigation, Writing- Original draft preparation. Salah K. Elsayed, Abdulrahman Babqi, Daniel Limenew Meheretie, Walid S. E. Abdellatif: Data curation, Validation, Supervision, Resources, Writing—Review & Editing, Project administration, Funding Acquisition.
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Abderraouf, B., Lakhdar, L.M., Abdelkader, B. et al. Experimental performance comparison of fixed and single-axis subfields in a large-scale outdoor photovoltaic power plant. Sci Rep 16, 12293 (2026). https://doi.org/10.1038/s41598-026-41570-8
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Scientific Reports volume 16, Article number: 9596 (2026) Cite this article
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The paradigm shift toward electric transportation is a necessary step in mitigating greenhouse gas discharges in connection with the internal combustion engine emissions. Nevertheless, the Electric Vehicle (EV) charging infrastructures predominantly rely on fossil fuel-based power generation, which again aggravates climate change. Imparting renewable energy sources for powering the charging systems is therefore essential, with photovoltaic (PV) power standing out as a scalable and portable solution. In PV-based charging setups, the power available from the panels can vary widely, especially when some modules fall under shade. To keep the charging process steady during such conditions, a smarter MPPT approach becomes necessary. In this work, a single-stage full-bridge converter operating with phase-shift control is combined with an Social group optimization based MPPT method to improve how the system reacts to these fluctuations. The converter has been designed so that the switches achieve soft-switching, which helps in cutting down losses and keeping the output voltage steady over different operating points. A 3 kW prototype was built and tested along with detailed simulations. Both sets of results show that the converter, together with the MPPT strategy, is able to draw consistent power from the PV array and continue charging the battery smoothly even when the sunlight changes abruptly. The system achieves a peak efficiency of 97%, representing a notable improvement over conventional dual-stage system. Additionally, the output voltage regulation is enhanced by 2%, demonstrating the viability of the proposed converter-MPPT architecture for future PV-powered EV charging stations with improved energy conversion efficiency and resilience under environmental uncertainties.
Electric Vehicle fleet is fast emerging across the globe. In Indian sub-continent perspective, the growth of EV has its impact on the promises rendered in COP 26¹. Attaining net zero commitment by 2070 is ambitious, but with the given development in the EV infrastructure and rigorous policies for renewable source deployment, it is not a distant dream to attain net zero². Among the renewable sources, the photovoltaic (PV) and Fuel cell (FC) are very compatible with EV drive and charging infrastructure. In fact, FC will be a very good candidate for direct EV drives as a coveted source³ as the energy density factor is very high. However, the high costs and complex technologies involved in hydrogen storage and handling make it a less pragmatic candidate for many applications. PV, on the other hand will be a handy source to be deployed in charging stations for two wheelers and three wheelers so that the grid power reliance can be reduced considerably⁴. The lack of charging infrastructure in developing economies poses stiff challenges for EV proliferation. The cost involved in building charging infrastructure as well as relevant communication protocols play a crucial role^5,6. Moreover, if the charging infrastructures are levied only from grid power, the mission of net-zero will face a major setback, as the predominant share of power is generated from fossil fuels such as coal. Therefore, the charging infrastructures can be built with PV array as source which makes the EV sector greener. But the major issues here are the inherent intermittency that PV possesses in nature. The output power-voltage (P–V) characteristics of a PV array are nonlinear and exhibit a unique maximum power point (MPP) corresponding to the optimal combination of voltage and current. MPPT algorithms are employed to identify this point in real time, using power electronic converters to regulate the operating point of the PV system⁷. While the impact of temperature on power output is relatively modest due to its logarithmic influence, irradiation plays a dominant role as it has a near-linear relationship with the output power. In most PV systems, the MPPT controller adjusts the duty cycle of the converter to locate the point at which the array delivers its highest power. The commonly used P&O and INC methods work reasonably well when the sunlight is uniform across the panel surface^8,9. P&O changes the operating voltage step by step and checks whether the power moves up or down, but it tends to keep oscillating around the best operating point. INC improves this behaviour by using the slope of the P–V curve to decide the direction of movement, although the method requires more computation because it relies on derivative information.
When part of the array is shaded, the output power curves develop several small peaks, and this makes the tracking process far more complicated. Under these conditions, both the basic and enhanced versions of P&O and INC often end up locking onto one of the local peaks instead of the true global maximum. A variety of MPPT schemes have been reported in literature, but many of them still struggle when the irradiance changes rapidly or when severe shading occurs. Issues such as slow response, unnecessary oscillations, and failure to move out of local traps remain common, which underlines the need for MPPT techniques that are more flexible and capable of handling such irregular operating conditions¹⁰. To overcome the limitations of conventional MPPT methods under partial shading, research has increasingly focused on global search, bio-inspired, and Artificial Intelligence (AI) based algorithms¹¹. These intelligent techniques are broadly classified into evolutionary (e.g., Genetic Algorithm, Differential Evolution) and bionic approaches, with the former gaining prominence in the 1990s for their population-based search and adaptability. Evolutionary algorithms like Genetic Algorithm (GA) and Differential Evolution (DE) rely on initialization, crossover, and mutation based on the principle of survival of the fittest^12,13. The Particle Swarm Optimization (PSO), inspired by swarming behaviour of birds and fish, remains to be the most effective among the global search algorithms¹⁴. The reason for its relevance till date is its optimum convergence accuracy and simple implementation. But, when the irradiation pattern tends to vary rapidly, the algorithm at times stagnates at a pseudo- peak. Therefore, the exploration on proposing inventive algorithms is at steady pace. The Grey Wolf Optimization (GWO)¹⁵, inspired by the hunting adoption of leadership hierarchy and hunting strategy of grey wolves, tries to balance both exploration and exploitation. This facilitates rational evading of local maxima during the search process. But here too, large steady-state oscillations prevail under dynamic insolation pattern. Another interesting algorithm, Hippopotamus Algorithm (HOA)¹⁶ is emulated by natural behaviour of hippopotamus. The tracking efficiency is high, but it involves higher computational effort. Other algorithms like MFO (Moth Flame Optimization) and Cuckoo Search Algorithm (CSA) have also been tried and tested, but these algorithms exhibit poor tracking reliability under fast-changing irradiance¹⁷. The recent advancement in deep learning computation has also been deployed in MPPT through DLCI (Deep Learning and Cognitive Inspired) neural decision models and learning architectures. The advantage is the speed of tracking is swift under learned conditions, but on the other hand, requires large training data. Artificial Bee Colony (ABC), and Grey Wolf Optimization (GWO) offer improved global search capabilities¹⁸, but face issues like slow convergence and increased complexity. Enhanced variants like E-PSO have attempted to address these limitations using fast-response digital signal processing (DSP) controllers¹⁹. Ant Colony Optimization (ACO), inspired by the foraging behaviour of ants, is valued for its ability to explore complex solution spaces and avoid local maxima due to its collective intelligence mechanism²⁰. However, its sluggish response in highly dynamic irradiance conditions limits its suitability for real-time MPPT applications where fast convergence is critical. Despite the individual strengths observed in various global MPPT strategies, the recurring limitations such as slow convergence, local trapping, or high computational burden warrant the exploration of more adaptive solutions. In this context, Social Group Optimization (SGO) has been employed in the present work due to its proven capability to balance exploration and exploitation through socially driven interactions²¹. Social Group Optimization (SGO) is chosen as the MPPT strategy because its two-phase search mechanism (improving and acquiring phases) provides a strong balance between exploration and exploitation, which is essential for reliably locating the global maximum power point (GMPP) in multi-peaked P–V curves under partial shading. The algorithm is parameter-lean, requiring only a self-introspection factor, which reduces implementation complexity compared to other global search techniques. Its update rules are computationally efficient and easily mapped to the PSFB control framework, making it suitable for embedded real-time applications. Benchmark studies demonstrate that SGO achieves competitive or superior solutions with fewer fitness evaluations than many existing metaheuristic counterparts, which directly benefits MPPT tasks where iteration budgets are constrained. Moreover, the mechanism inherently mitigates steady-state oscillations by guiding particles based on both the global best and peer influence, yielding faster convergence with stable operation.
Resonant converters are an appropriate choice for battery charging, as zero-voltage switching (ZVS) and zero-current switching (ZCS) are achieved²². The non-isolated topologies of resonant converters are least preferred due the concerns like electromagnetic interference, increased common mode noise, and need for competent protection due to the absence of galvanic isolation²³. Among the isolated topologies, the full bridge converter is advantageous, as it can handle high-power by utilizing the entire transformer during operation. Besides that, the four switches in the topology reduces the current stress on individual components, leading to lower conduction losses²⁴. Apart from full bridge there are numerous topologies of resonant converters, but the prudent choice needs to be based on the power capacity, efficiency requirement and specific application. The half bridge circuit possess lesser number of switches, but the power handling capacity is less. The typical buck, boost converters also quite suitable for the charging circuits but the lack of galvanic isolation raises protection and common mode noise issues. The flyback topology provides galvanic isolation, but the single-switch design adds stress, and the full potential of the ferrite-core transformer cannot be utilized due to inevitable two-phase charging and discharging operations. The interleaved topology is better but the increased in components and control complexity will exist. The push-pull topology is apt for high power as transformer is centrally tapped and two switches are employed. The transformer core saturation will happen when the controller is not prudently chosen, the full bridge converter provides a robust solution for battery charging due to its efficiency, flexibility, and isolation capabilities.
The selection of an appropriate control strategy is equally crucial for optimizing the performance and efficiency. The advanced controllers like sliding mode control and model predictive control can handle multi variable problems and could excel in non-linear changes in the system, but when it comes to implementation, high expertise is in demand for handling the coding complexity. However, these controllers are reliable for real-time forecasting and dynamic optimization, and they establish good response under rapidly changing environmental and load conditions²⁵. Fuzzy logic control (FLC) provides flexibility and handles uncertainty well but the execution and the output reliability depend on the versatility of the rule set. Adaptive control scheme is very adjustable to dynamic changes in the system, but the design complexity is high. Among all control schemes the phase shift modulation stands out as a particularly effective control strategy for full-bridge converters used in battery charging²⁶. To regulate the output voltage and efficient power transfer the phase difference between the two halves of the converter have been adjusted. It provides superior efficiency, reduced component stress, and excellent performance across a wide range of operating conditions, making it a highly advantageous choice in this context. Figure 1 presents a typical charging infrastructure with PV, resonant power electronic converter, and advanced MPPT controller cuddled with modulation schemes. This hybrid control scheme facilitates competitive maximum power tracking during shading as well ensures optimized battery charging. While numerous MPPT techniques and power converter topologies have been proposed independently, an integrated strategy that robustly handles both global tracking under partial shading and high-efficiency power conversion remains underexplored. Although a wide range of MPPT algorithms (P&O, INC, PSO, GWO, HOA, MFO, CSA, ACO, ABC, DE, DL-based methods, etc.) and several DC-DC converter topologies such as buck, buck-boost, flyback, interleaved, half bridge and full-bridge have been extensively studied, these two domains are largely explored independently. Existing MPPT-focused works primarily address global peak tracking under partial shading but do not consider how the chosen converter influences switching behaviour, soft-switching windows, or power-transfer efficiency. Conversely, converter-oriented studies optimise ZVS/ZCS operation and efficiency but overlook the effect of dynamic and multi-peaked PV characteristics on control stability and energy extraction. The research gap lies in the lack of a unified and coordinated co-design approach that simultaneously integrates a global MPPT technique with a high-efficiency resonant converter for EV battery charging, especially under rapidly varying irradiance and partial shading. This missing coordination results in sub-optimal system performance when both global tracking accuracy and converter soft-switching requirements must be satisfied concurrently. Although numerous MPPT strategies and converter control methods have been explored individually, there are no studies that bring a socially inspired global MPPT algorithm and a phase-shift full-bridge (PSFB) resonant converter together within a single, unified framework. The adaptive behaviour of SGO allows it to identify the global peak even when irradiance varies rapidly, while the PSFB resonant stage ensures isolated power transfer, reduced switching losses, and improved operational safety. When combined, these two elements complement each other the MPPT algorithm consistently extracts the available PV power, and the converter maintains high-efficiency regulation over a wide range of operating conditions.
This integrated concept also builds upon the authors’ earlier work on socially inspired MPPT approaches, enabling the present system to remain lightweight, scalable, and suited for practical hardware implementation. Motivated by this gap, the proposed architecture couples an SGO-based MPPT technique with a PSFB resonant converter and investigates their coordinated operation under both uniform and partial-shading scenarios. The findings show improved tracking accuracy, enhanced conversion efficiency, and stronger reliability, thereby addressing the identified gap and offering a practical pathway for efficient PV-powered battery charging in EV applications.
PV aided EV charging station.
The primary contributions of this research are as follows:
An adaptive MPPT scheme based on Social Group Optimization (SGO) is employed to improve power extraction from the PV array, with its robustness demonstrated under various partial-shading patterns.
A high-efficiency PSFB Full bridge resonant converter is developed, incorporating soft switching to establish enhanced power delivery.
A unified phase-shift control approach is introduced to coordinate MPPT and battery charging, enabling natural ZVS through device capacitances and transformer leakage, which helps lower switching losses.
The structure of the paper is as follows: “SGO algorithm based PSFB for battery charging” section deals with mathematical modelling of the photovoltaic system. The partial shading conditions are critically analysed, highlighting the impact on output characteristics such as multiple maximum power points. To address this the SGO algorithm has been introduced. “Phase shift full bridge resonant converter” section deals with PV fed phase shift full bridge resonant converter with efficient power conversion. The simulation validation and hardware implementation which ensures the efficiency improvement, soft switching characteristics and voltage regulation. In addition, the integration of SGO algorithm with phase shift full bridge resonant converter under partial shading condition provides improved maximum power point tracking and efficient converter performance. “Conclusion” section presents the key findings of the MPPT algorithm and the converter efficiency.
A PV cell’s equivalent circuit is depicted as a current source connected in parallel with leakage elements, represented by a shunt resistance R_sh. Figure 2 Shows that s single solar cell modelling which should be expandable as a PV array. Voltage is produced by the solar panel as a result of sunlight irradiation and the panel’s temperature. The Eqs. (1–3) are derived from the equivalent circuit and formulated through the diode equation and Kirchoff’s rules.
Equivalent circuit of pv cell¹⁹.
Here the diode current is considered as equal to short circuit current.
From the equivalent circuit
Maximum power refers to the peak instantaneous power determined by the prevailing environmental conditions. It is calculated as the product of voltage and current at that moment, as expressed in the Eq. (4)
Figure 3a illustrates the string arrangement for uniform shading which is providing 3 kW power to the full bridge converter with irradiation of 1000 w/m². Figure 3b shows that the partial shading in PV systems occur due to the hindrances that obstruct the exposure of PV panels to sunlight. These obstructions may happen due to natural blockages like trees, buildings etc. or due to man-made ones like chimneys, utility poles etc. or even due to weather and environmental disturbances like clouds, dust, debris etc. Due to the shading of even fewer cells in a panel, the net output power decreases. The cells with shading acts as a resistive load and it do emit heat instead of electric power. In a standard PV panel, the cells are connected in series, and shaded cells generate less current. This reduced current becomes the overall current, leading to a decrease in the total power output. Therefore, there may be 50% of power loss even if there is 10% of shading. Bypass diodes are prudent choice for mitigating the impact of shading. These diodes facilitate the blocked current of the shaded cells to get bypassed and thereby aiding to have better efficiency levels for the entire solar array. This ensures more consistent energy production, especially in environments prone to partial shading. When bypass diodes are used, a key issue is the formation of multiple power peaks in the current-voltage (I–V) and P–V curves. Under uniform sunlight, the P–V curve has a single, well-defined maximum power point (MPP). However, if part of the PV array is shaded, the bypass diodes redirect current around the shaded panels, resulting in multiple power peaks, one corresponding to the unshaded area and another to the shaded area.
Solar Photovoltaic system under partially shading (a) string arrangement for uniform shading (b) string arrangement for non-uniform (c) shading characteristics analysis for multiple peaks.
Figure 3c Depicts the string configuration of a partially shaded PV array, where the I–V and P–V curves exhibit multiple power peaks. Traditional MPPT algorithms, which scan the P–V curve to locate the maximum power point, often get stuck at local peaks, resulting in significantly reduced power output. To overcome this limitation and ensure the delivery of maximum global power, this study employs an intelligent SGO based global search algorithm.
The SGO algorithm makes most out of the individual knowledge of participants in a group and achieve the goal. The members in a group, based on their competencies can be named as leaders, followers²¹.The leaders share their experience, and the followers and learners acquire the knowledge shared and with the experience they gain in the search process move towards the objective. The SGO consists of two phases: (i) Improving Phase (ii) Acquiring Phase. The first phase intends to diversify of the search by different regions of the solution space. This phase investigates the search space to identify potential solutions. The second phase is used to utilize the regions of the search space. Individuals share and leverage the collective knowledge within their social groups to concentrate their efforts on areas with potential optimal solutions.
In this phase, the top performing candidate of each social group, referred to as the global optimum (g_opt), shares knowledge with other members of the group. This knowledge sharing process enhances the performance of the participating members. The objective function for maximization is defined as g_opt = max {F_i | i = 1, 2, …., M}. where M represents the total number of candidates in the group, and F_i is the fitness value of the i-th candidate. Additionally, during each iteration of this phase, knowledge is exchanged and updated among the candidates, as represented by Eq. (5).
where ξ is random selection, (:{text{Y}:}_{text{n}text{e}text{w},text{j}}^{text{t}}) is the Updated new position, (:{upbeta:}) is the learning factor, (:{text{g}}_{:text{o}text{p}text{t}}^{:text{t}}) is the current best solution in the group at iteration t, (:{text{Y}}_{text{o}text{l}text{d},text{j}}^{text{t}}) previous position. After calculating (:{text{Y}:}_{text{n}text{e}text{w},text{j}}^{text{t}}) its fitness is evaluated. If the new state performs better than the old one in terms of the objective function, the update is accepted.
During this phase, each group member gains knowledge from the most knowledgeable individual and engages in random interactions with other members. Candidates acquire new insights both from one another and from the top performer, referred to as g_best if another individual surpasses g_best in knowledge, they will take the position of the best candidate, as illustrated in Fig. 4. the updated new knowledge valu can be calculated by Eqs. (6) and (7).
If the selected member (Q_r) has lower knowledge than the current candidate (Q_j)
If the selected member Q_r has greater knowledge than the current candidate Q_j
where,
Q_j = The current candidate.
Q_r = A randomly selected group member.
(:{text{Z}:}_{text{n}text{e}text{w},text{j}}^{text{k}}) = The updated new knowledge value of candidate Q_j in the k^th dimension.
(:{text{Z}}_{text{o}text{l}text{d},text{j}}^{text{k}}) = The previous value of candidate Q_j in the k^th dimension.
(:{text{g}}_{text{b}text{e}text{s}text{t}}^{:text{k}}) = Best knowledge in the group.
(:{phi:}_{1}) = Learning coefficient component.
(:{phi:}_{2}) = Global learning coefficient.
k = Dimension index.
Social group optimization with individual group.
The process begins by randomly initializing the duty cycle of the PSFB within a defined range, constrained by the open -circuit voltage (V_oc) and short-circuit current (I_sc) of the PV system. By using this initial duty cycle, the power output of the PV system is computed. The duty cycle corresponding to the highest power output is identified as the leader, while the remaining duty cycles are categorized as learners. To achieve maximum power point tracking, the search mechanism is updated iteratively, with solutions progressing toward the leader. The duty cycles represent the participating members in this optimization framework.
In the exploration phase, candidates moved based on their previous positions and the influence of the best-performing member. This phase is represented as Eq. (8)
(:{text{D}}_{text{n}text{e}text{w},text{j}}^{text{k}})—Updated duty cycle of the candidate j at iteration k.
(:{text{D}}_{text{o}text{l}text{d},text{j}}^{text{k}})—Previous duty cycle of candidate j.
(:{upgamma:})—Self adjustment factor in the range (0,1).
ρ—Random coefficient to introduce variability from (0,1).
(:{text{G}}_{text{b}text{e}text{s}text{t}}^{:text{k}})—Current best solution in the group.
The candidates further refine their solutions based on comparisons with randomly selected alternatives. This as follows in the Eqs. (9) and (10).
If (:{text{D}}_{text{n}text{e}text{w},text{j}}^{text{k}}) performs better than (:{text{D}}_{text{r}text{a}text{n},text{j}}^{text{k}}):
If (:{text{D}}_{text{r}text{a}text{n},text{j}}^{text{k}}) performs better than (:{text{D}}_{text{n}text{e}text{w},text{j}}^{text{k}})
(:{text{D}}_{:text{r}text{a}text{n},text{j}}^{:text{k}})—Duty cycle of a randomly selected candidate.
(:{{upsigma:}}_{1}:,) (:{{upsigma:}}_{2})—Random scaling influencing local and global adjustments.
(:{text{g}}_{text{b}text{e}text{s}text{t}}^{:text{k}})—Influencing of the best-performing duty cycle.
The partially shaded PV array is optimized through SGO MPPT, and it is hybridized with the PSFB converter for battery charging in EV bays. This section details the SGO MPPT, full bridge design and resonant operation and phase-shift modulation. Figure 5. presents PV aided charging system through the full bridge resonant converter and hybrid SGO phase shift control scheme. The PV system consists of 12 series connected modules of 275 W yielding a voltage of 469 V (12 × 39 V) at open circuit and 390 V (12 × 32.5 V) at maximum power.
PV aided phase shift full bridge resonant converter.
The phase shift full bridge resonant converter is used to regulate the output power while frequency is constant which implies to reduce the magnetic design. The converter achieves zero voltage switching (ZVS) using transformer leakage inductance and MOSFET capacitance, reducing switching losses and improving efficiency. The PSFB converter can be used for wide input and output voltage and provides a fast transient response which is suitable for dynamic loads. At light loads, it maintains good performance through burst mode control. The PSFB converter is having some additional characteristics such as (i) galvanic isolation is provided by the high frequency transformer which ensures the safety and ground loop interference (ii) smooth control of power flow is achieved by modulating the phase difference between the two inverter legs, eliminating the need of duty cycle variation. (iii) reduced switching stress and EMI due to zero voltage switching in the switch which cause smaller magnetic and filter components. (iv) flexible transformer ratio allows adaptation to a wide range of input PV voltages and battery charging voltages. (v) compatibility with digital control platforms, enabling seamless integration with MPPT algorithms and closed loop voltage and current regulation. The bridge converter consists of four switches S₁, S₂, S₃, and S₄ on the primary side of the high-frequency transformer, with a centre taped rectifier connected on the secondary side. The battery pack is rated at 3.3 kW with 48 V as the operating voltage. The phase shift full bridge resonant topology is employed here to ensure efficient power delivery. The phase shift controller ensures good voltage regulation, achieves ZVS, and provides better efficiency with reduced power losses. The resonant frequency (f_r) of the tank circuit is determined by the specified maximum transition time and the requirement for stored inductive energy. The components of this tank circuit consist of the resonant inductor (Lr) and capacitor (Cr) which are derived from the output capacitors of the two switches. The resonant tank parameters are calculated using the Eqs. (11–14).
The resonant capacitance is
The resonant inductance is
Phase 1 (0 to t₁)
Figure 6. illustrates modes of operation of PSFB converter. At the start, at time t = 0, the primary side current is zero. As time progresses from 0 to t₁. Switch S₁ begins conducting, as illustrated in Fig. 6a. During this initial phase, the primary current remains constant due to resonance, which is determined by the transformer leakage inductance (I_lk). When diode D₁ starts conducting, energy is transferred from primary to secondary side. Following this, switch S₄ is turned off, causing the transformer to enter a short-circuit state, and the voltage across the transformer drops to zero. The parasitic output capacitance (C_oss) of S₄ is charged, while the C_oss of switch S₃ discharges.
Based on the phase 1 equivalent circuit of the PSFB²⁷, the primary current and voltage across the circuit are calculated as per Eqs. (15) and (16)
Converter modes of operation (a) Phase 1 (0 to t₁), (b) Phase 2 (t₁ to t₂), (c) Phase 3 (t₂ to t₃), (d) Phase 4 (t₃ to t₄) (e) Key waveform of PSFB.
Phase 2 (t₁ to t₂)
At instant t₁, when switches S₁ and S₄ are turned off, the inductor current (I_L) discharges the parasitic capacitances (C_oss) of S₁ and S₄, while simultaneously charging the capacitances of S₂ and S₃ in preparation for the next switching transition as shown in Fig. 6b.
The current and voltage of the primary can be expressed in Eqs. (17) and (18)
Phase 3 (t₂ to t₃)
When switches S₁ and S₄ turn off, the diagonal switches S₂ and S₃ will begin conducting. The current path on the primary side will shift, passing through the parasitic capacitance (C_oss) of switch S₁. This current path helps raise and lower the voltage across switch S₂, enabling it to transition under ZVS conditions. The body diode of S₂ temporarily conducts to clamp voltage, maintaining control over the primary current. Once S₂ begins to turn on, switch S₃ (already conducting) will allow power transfer to proceed through the transformer as shown in Fig. 6c.
From Eqs. (19) and (20) the current through the diode rectifier D₁ and D₂ is
Phase 4 (t₃ < t < t₄)
Now, the phase-shifted cycle is now equivalent to a standard square wave conversion. After switch S₄ turns off, the cycle repeats from the initial stage. Switch S₃ will remain off, but current flows through the parasitic capacitance, increasing the input voltage from zero to the source voltage as shown in Fig. 6d. Key waveform of PSFB is shown in Fig. 6e. All these modes of operation are presented in Table 1.
To optimize voltage regulation and efficiency, it is crucial to carefully select key parameters, including the parasitic capacitance of the switches, the shim inductor, the transformer core, and its magnetising inductance. On the secondary side, critical considerations include the use of a half- wave rectifier and the design of the output filter. In a PSFB topology, the transformer plays avital role in transferring energy from the PV input to the battery charging output through magnetic coupling. It facilitates resonant operation by managing the phase shift between switching pulses and achieves voltage transformation between the primary and secondary sides based on the turn’s ratio.
The turns ratio is calculated by using Eqs. (21)–(22) and from the magnetising inductance which is mentioned in Eq. (23)
The PSFB operates in voltage mode control for low values and in peak current mode control in for high values, magnetizing inductance (L_mag) can be calculated by Eq. (24)
The transformer primary and secondary current ca. be calculated by Eqs. (25)-(26)
To maintain the continuous current the inductor has been selected and it reduces the electromagnetic interference, and it helps to improve the efficiency. The output inductor and capacitor can be calculated by Eqs. (27) and (29).
The transient voltage is selected for 10% transient voltage (V_t)
The selection of shim inductor is based on the energy required to achieve ZVS in primary side and based on the selection of parasitic capacitance of switch. The minimum value of the shim inductor can be calculated by Eq. (30). Circuit parameters and their corresponding values are given in Table 2)
Simulation results of MPPT (a) Simulation result of partial shading pattern (b) simulation result of dynamic shading.
Simulation results of PSFB (a) Primary side voltage of High frequency transformer (b) Primary side current of the PSFB (c) Gate signal of MOSFET (d) Secondary side voltage of the transformer (e) Output voltage and Output Current (f) ZVS and ZCS implementation (g) CV mode of the battery (h) CC mode of the battery (i) 30% SoC of the battery.
The PSFB validation was conducted in MATLAB/SIMULINK with an input voltage of 400 V. The overall simulation results with three different optimization methods deployed are shown in Fig. 7. Figure 7a presents the dynamic changes in the irradiation from uniform to partial and compares the competencies of the global search algorithms. For every 2-sec there is a variation in the irradiation pattern. Throughout the full simulation duration (0–8 s), SGO consistently delivers fast convergence, minimal overshoot, and smooth transitions during step changes in power demand. The zoom view of simulation result (0–0.5 s) further emphasizes SGO’s rapid start-up response, with stable tracking of the 3000 W power target in under 0.1 s, while GWO and PSO exhibit delayed and oscillatory behaviour. Voltage regulation remains close to the target of 400 V with SGO, showing the least deviation during transients. Current tracking is similarly stable and noise-free under SGO, ensuring reduced stress on power components. The performance comparison presented in Fig. 7b includes the P&O, PSO, GWO and SGO. The simulation results clearly demonstrate the superior performance of the Social Group Optimization as it quickly reaches the maximum power point with minimal fluctuation, while P&O takes longer and shows more oscillation. The voltage and current graphs also show that SGO stabilizes faster than the others. During 0–2 s, when the irradiation is uniform, the P&O actively participates and can track the peak power 3000 W but the major drawback is the power output is oscillatory in nature. The GWO and PSO perform better than P&O but are not as fast or stable as SGO. The duty cycle graph confirms that SGO adjusts more smoothly and quickly. Overall, SGO gives the best performance with fast response and stable output, while P&O performs the worst due to slow response and high fluctuations. The Table 3 compares the performance of SGO, GWO, PSO, and P&O algorithms under uniform and partial shading conditions. It is inferred that the conventional P&O will have least power tracked and for simpler understanding if the search is related with the multi peak pattern represented in Fig. 3c, the tracked power will be only 550 W as stated in Table 4. Table 5 illustrates a comparative analysis of PSFB converter efficiency under partial shading conditions using different MPPT algorithms. The SGO algorithm achieved the highest maximum PV power of 1393 W and a corresponding PSFB output of 1261 W, resulting in the highest observed efficiency of 90.6%. GWO, PSO, and P&O also maintained similar efficiencies around 90.5%, though they extracted slightly less power from the PV source Fig. 8 illustrates the MATLAB/Simulink results of the PSFB converter. In the MATLAB simulation, ideal components such as the MOSFET, diode, high-frequency transformer, and controller are used, resulting in lossless operation. The suitable parasitic capacitance and shim inductance are chosen as 100 pF and 16 µH, respectively, for operating a 3-kW battery charging station. To ensure proper functioning of the primary and secondary voltages and currents of the high-frequency transformer, the leakage inductance of the transformer is considered as the resonant inductor. Figure 8a and b illustrate the primary-side voltage and current of the transformer. The single MOSFET gate pulse is shown in Fig. 8c. In this PSFB, ZVS is attained by utilizing the energy stored in the power transformer’s leakage inductance to softly switch each of the four power MOSFETs. Figure 8d illustrates the secondary-side current of the transformer. The simulation is verified with both a resistive load as well as battery. Figure 8e shows the output voltage and current for the resistive load. Figure 8f illustrates the achievement of ZVS in the PSFB converter with respect to S₁ and S₄. When the SoC is 30%, the battery charger operates in constant current (CC) mode, during which the battery voltage increases gradually. Once the battery voltage reaches 54.6 V, the converter transitions from constant current (CC) to constant voltage (CV) mode, as shown in Fig. 8g–i.
Table 2 presents design parameter of the system. The PSFB converter operates at a frequency of 100 kHz, with maximum duty cycle of 50%. Figure 9. Presents the experimental set-up of the proposed system comprising the PV emulator, PSFB converter and battery storage system. The measuring devices current probe, differential voltage probe is also presented in the Figure. The Fig. 10. illustrates a detailed schematic of a PSFB on a printed circuit board (PCB), with key components labelled for identification. The system starts with a DC EMI filter (1), which prevents electromagnetic interference from affecting the circuit. Additionally, Voltage Regulator (2), ensuring stable voltage levels for the system’s operations. The driver unit (3) controls the power transistors, enabling efficient switching, while the PSFB controller (4) generating PWM pulses to the PSFB converter. A buffer (5) has been added to stabilize the transfer of signals components. The microcontroller unit (MCU) (6) is the core processor, coordinating the overall control of the system. Energy is transferred by using the high-frequency transformer (7), isolating different sections of the circuit and adjusting voltage levels. The battery current sensing unit (8) monitors current flow to ensure efficient charging or discharging of the battery. The PSFB (9) handles high-efficiency DC-DC conversion, and finally, the diode rectifier (10) converts AC into DC to charge a battery. The emulator-based validation demonstrates the real-time feasibility of the proposed SGO-based MPPT with PSFB charging, confirming that the algorithm can be executed efficiently on embedded hardware, adapt rapidly to dynamic irradiance changes, and maintain stable converter operation with minimal oscillations, thereby improving overall energy harvesting. These outcomes suggest strong potential for deployment in practical PV-powered charging systems and scalability to larger standalone or grid-integrated applications. While the present work has been carried out using a PV emulator rather than an outdoor array, and the performance depends on appropriate tuning of algorithmic factors, these aspects mainly indicate directions for extended field validation and refinement rather than fundamental drawbacks.
Hardware set up for measurement.
PCB layout of PSFB.
Performance characteristics of photovoltaic system (a) I–V and P–V curve for V_mp=400 V (b) Irradiance curve at 1000 W/m² (c) -V and P–V curve for V_mp=500 V (d) Irradiance curve at 1000 W/m².
The Fig. 11. presents the performance characteristics of a PV system under varying irradiance and temperature conditions. The Fig. 11a. Shows the I–V and P–V curves of the PV module. The current decreases as voltage increases, while the power initially rises, peaking at the maximum power point (MPP) before declining. The maximum current is about 5.7 A, with power peaking around 1820 W at a voltage of 430 V. The Fig. 11b. Shows constant irradiance at 1000 W/m² and temperature at 25 °C over time, indicating standard test conditions. The Fig. 11c. Shows similar I–V and P–V characteristics but at higher irradiance or temperature, with the current reaching 6.2 A and power peaking at 2400 W at a higher voltage range (500–600 V). Figure 11d. illustrates the solar irradiance remaining at 1000 W/m², while the temperature has increased to 50 °C, which provides impact the system efficiency, leading to a shift in the maximum power point.
Figure 12 illustrates how the phase shift between the primary side switching signals controls the transfer of energy from the 400 V input to the transformer’s secondary side, operating with a 50% duty cycle. Figure 13 illustrates the phase-shifted gating signals of S1 and S2. Figure 14. shows that with a constant input voltage of 366 V, the output current of 62.5 A increases as the load demand rises, corresponding to a time interval of 5µs.The phase shift adjusts accordingly, regulating the amount of energy transferred to the secondary side to meet the increased load. As shown in Fig. 15. the primary side current and gate signal are depicted. The results indicate the achievement of both ZVS and ZCS. It is observed that when the primary side current is zero, the gate signal is deactivated, allowing the switch to achieve soft switching under zero current conditions. Additionally, at full load, the primary side current is higher, making it easier to achieve ZVS for the leading leg. Figure 16 shows that the varying input voltage with constant output voltage. Figure 17 illustrates the relationship between the transformer’s primary voltage and primary current. The circulating current is sustained by the transformer’s leakage and magnetizing inductance, which maintain the current flow during the freewheeling interval, even when the primary voltage is zero. Figure 18a. shows the system output power under various levels of irradiation while maintaining a constant panel temperature, along with the PSFB converter efficiency at 97%. As a result, the power increases with the irradiance, while the converter maintains an efficiency above 80%. At full load, the converter achieves 97% efficiency with reduced losses. Figure 18b. shows the system output power versus efficiency under constant irradiance and varying temperatures, with the converter maintaining an efficiency above 80%.
Ch1 = voltage across PSFB 200 V/divand Ch2 = output voltage of 20 V/div witht = 5 μs/div.
Ch1 = V_gs2 of 200 V/div Ch2 = V_gs1 of200 V/div.
Ch1= I_o of 30 A/div and Ch2= V_in of100V/div.
Ch1 = Ipirmary and Ch2 = gate sourcevoltage (V_gs1).
Ch1 = V_in of 100 V/div and Ch2 = V_o of20 V/div.
Ch1 = V_in of 200 V/div and Ch2= IPrimaryof 3 A/div.
Efficiency curves of the PSFB converter for different solar panel parameters (a) The output power vs. efficiency of the PSFB converter for constant temperature with different irradiation (b) The output power vs. efficiency of the PSFB converter for constant irradiation with different temperature.
Efficiency with load variation.
Figure 19 shows the efficiency of the PSFB converter compared to the PWM-based conventional resonant converter under various load conditions. It is observed that the efficiency improves by 1% at full load and by 2% at light load due to the reduction in switching losses achieved through phase-shift control.
This research work advocates a phase shift modulation and social group power tracking algorithm controlled full bridge DC-DC converter for EV application. The developed controller is highly dynamic in responding to irradiation changes and partial shading among the panels in the array. Also, the phase shift full bridge resonant converter achieves ZVS ensuring minimized losses and voltage regulation. The experimental and simulation results demonstrate that the system achieves a high efficiency of 97% under variable input voltages and maintains voltage regulation within ± 2%, ensuring stable power delivery to EV loads. These outcomes validate the effectiveness of combining intelligent control algorithms with soft-switching power converter topologies to enhance the reliability and performance of EV charging systems. However, the proposed system possess some limitations and they are : The proposed system has been developed under controlled operating conditions within tested cases. However, the uneven shading conditions may still demand fine tuning to ensure complete real-time adaptability. Also, during light loads, the ZVS margin may experience a dip which results in increased switching losses. Future scope:
Future work can explore integrating adaptive control techniques with the social group optimization power tracking algorithm to further enhance real-time adaptability under highly dynamic environmental conditions such as non-uniform irradiance.
The proposed work can be further extended by integrating multiple renewable sources through a multiport converter topology, enabling coordinated energy management across diverse inputs such as solar, wind, and battery systems. Additionally, the SGO-based MPPT algorithm can be evolved into a predictive or adaptive control framework by leveraging machine learning techniques or model predictive control (MPC) strategies.
Data Availability: The datasets used and/or analysed during the current study available from the corresponding author on reasonable request.
Random number
Random number
Junction capacitance
Output capacitance
output capacitance between drain and source
Equivalent parallel capacitance
Resonant capacitance
Cognitive parameter
Social parameter
Maximum duty cycle
Resonant switching frequency
Switching frequency
Diode current
Diode current
Magnetising current
Maximum current
Output inductor
Primary peak current
Saturation current
Primary RMS current
Secondary RMS current
Boltzman constant (1.38 × 10–23 J/K)
Leakage inductance
Resonant inductance
Magnetising inductance
Output inductance
Shim inductance
Maximum power of the PV panel
Primary turns
Secondary turns
Transformer turns ratio
Output power
Charge of electron (1.602 × 10–19 C)
Series resistor
Shunt resistor
Time taken to L_out changes from
Absolute temperature of the panel
Output voltage
Photovoltaic voltage
Drain source resistance
Maximum inertia weight
Minimum inertia weight
Diode ideal constant
Output ripple current 90% to full load
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The authors gratefully acknowledge the support received under the Teachers Associateship for Research Excellence (TARE) Scheme, File No. TAR/2022/000547, funded by the ANRF – Anusandhan National Research Foundation (formerly SERB). The research work was carried out at the Renewable Energy Research Laboratory, SRM Institute of Science and Technology, Kattankulathur.
Department of Electrical and Electronics Engineering, SRM Institute of Science and Technology, Kattankulathur, Tamil Nadu , 603 203, India
Jayachitra Jayaraman & Sridhar Ramasamy
Department of Electronics and Instrumentation Engineering, SRM Valliammai Engineering College, Kattankulathur, Tamil Nadu, 603 203, India
Srinivasan Vadivel
Department of Electrical and Electronics Engineering, National Institute of Technology, Puducherry, 609 609, India
S. Thangavel
Department of Electrical, Telecommunications and Computer Engineering, Kampala international university, Kampala, Uganda
Hassan Abdurrahman Shuaibu
AIST (FREA), Fukushima Renewable Energy Institute, National Institute of Advanced Industrial Science and Technology (AIST), Fukushima, Koriyama, 9630298, Japan
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Jayaraman, J., Ramasamy, S., Vadivel, S. et al. Social group algorithm-based MPPT coupled with phase shift resonant converter for battery charging through partially shaded PV systems. Sci Rep 16, 9596 (2026). https://doi.org/10.1038/s41598-025-31674-y
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MSERC Notifies DRES Regulations 2026 To Boost Grid-Connected Renewable Energy Adoption In Meghalaya  SolarQuarter
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Global corporate funding in the solar sector reached $11.1 billion in the first quarter of 2026, with debt financing at its highest level in more than 10 years, says Mercom Capital Group.
Image: Fabersam, Pixabay
From pv magazine Global
Solar sector debt financing reached $8.9 billion in the first quarter of 2026 – the highest level in more than a decade – while project acquisitions hit 18.4 GW, the most since 2022, according to Mercom Capital Group’s latest quarterly funding and mergers and acquisitions report.
Debt financing drove the quarter, reaching $8.9 billion across 28 deals – the highest level in over a decade, Mercom said. Venture capital funding totaled $1.1 billion across 17 deals, down 21% year over year, while public market financing reached $1.1 billion across eight deals.
The five largest VC-funded companies in the quarter were Inox Clean Energy at $343 million, Clean Max Enviro Energy Solutions at $165 million, Amarenco at $150 million, GREW Solar at $118 million, and Radiance Renewables at $100 million.
Solar project acquisitions totaled 18.4 GW – the highest capacity since 2022. Developers and independent power producers accounted for 11.9 GW of acquisitions, followed by investment firms and infrastructure funds at 3.8 GW. Utilities acquired 830 MW. The quarter included 28 corporate mergers and acquisitions transactions.
“Improved policy clarity and strong demand led to an increase in solar funding and M&A activity in Q1 2026,” said Raj Prabhu, CEO of Mercom Capital Group. “Investments remained focused on assets that can advance in the near term, as projects moved forward following earlier policy and financing uncertainty, and developers accelerated timelines ahead of tax credit milestones.”
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Central inverters accounted for 51% of the total shipments
May 5, 2026
Follow Mercom India on WhatsApp for exclusive updates on clean energy news and insights
In 2025, inverter shipments to solar projects in India increased 40.8% compared to 2024, driven by record installations and a strong project pipeline targeted for commissioning in the first half of 2026, ahead of the phased reduction in interstate transmission systems charges waiver. The upcoming ALMM-II deadline created uncertainty around cells and module availability, prompting developers to accelerate project execution during the year.
Sungrow India, Sineng Electric, TBEA Energy India, FIMER India, and Ginlong (Solis) Technologies were the leading solar inverter suppliers in India in 2025, according to Mercom’s recently released India Solar Market Leaderboard 2026 report.
The report provides insights into the market share and shipment rankings of industry leaders across the Indian solar supply chain.
Sungrow led the market, followed by Sineng Electric and TBEA Energy India in second and third place, respectively, while FIMER India and Ginlong (Solis) Technologies rounded out the top five.

The inverter market in 2025 remained highly concentrated, with Sungrow Power Supply leading the segment by capturing nearly one-third of the market share, supported by scale, competitive pricing, and a deep presence in utility-scale projects.
Sineng Electric ranked second, capturing over 19% of shipments in 2025, reflecting strong order conversion from utility-scale and central procurement projects, along with a broader shift toward Chinese suppliers gaining share through competitive pricing and faster delivery.
TBEA Energy India ranked third, with its market share declining to about 18%, while FIMER India’s shipments fell to nearly 7%. These declines indicate weakening competitiveness among some established inverter suppliers.
The inverter market is also evolving in line with recent regulatory changes. The Bureau of Energy Efficiency (BEE) has made efficiency standards and labeling mandatory for inverters up to 100 kW, pushing manufacturers to improve product performance and comply with defined benchmarks. In parallel, the Ministry of New and Renewable Energy (MNRE) has introduced stricter communication protocols for inverters, requiring secure data transmission to improve monitoring and visibility of rooftop solar systems.
At the same time, MNRE extended the BIS compliance deadline for higher-capacity inverters, providing manufacturers additional time to meet quality and safety standards. The ministry also issued draft guidelines on secure rooftop solar data and inverter testing, encouraging the adoption of improved telemetry and cybersecurity features. These measures are guiding the market toward more uniform testing and certification processes, requiring manufacturers to comply early to remain competitive.
String Inverters
TBEA Energy India, Sungrow India, Sineng Electric, Ginlong (Solis) Technologies, and NingBo Deye Inverter Technology were the top solar string inverter suppliers.
String inverters accounted for 49% of the solar inverter shipments in 2025.

Central Inverters
Central inverter supplies surpassed string inverters in 2025, accounting for approximately 51% of the total shipments during the period.
Sungrow India, Sineng Electric, FIMER India, TBEA Energy India, and TMEIC were the top solar central inverter suppliers for 2025.
The growth of central inverters was supported by rising utility-scale solar project commissioning and the increasing standardization of large projects in Gujarat and Rajasthan, where higher power density is required. In comparison, demand for string inverters remained stable, driven by continued adoption in rooftop and smaller-scale solar installations.
Mercom’s Market Leaderboard report published annually, covers the market landscape across the entire supply chain. For the detailed and comprehensive report, click here.
Our Market Share Tracker provides insights into the solar market competitors and their growth rates on a quarterly basis.
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Bluefield said it will advance a pipeline of utility-scale floating solar PV across the UK.
May 5, 2026
Having commissioned analysis that showed 40GW floating solar could be delivered in the UK by 2050, Bluefield Solar has launched a new business unit focused on the technology.
The utility-scale solar owner-operator launched the floating solar PV (FPV) business through its development arm and said it will now advance a pipeline of utility-scale FPV projects across the UK.
Bluefield commissioned analysis from independent consultancy CBI Economics that found that FPV is a “major growth area” for UK renewables. 
The company already owns and operates an FPV installation at the Queen Elizabeth II Reservoir, which the largest floating solar plant in the UK, at 6.3MW, and said it sees FPV as a strategic complement to ground-mounted solar, offering rapid deployment and the ability to be co-located with industrial and water-treatment demand. 
The largest approved solar plant in the UK is a 40MW project by port operator Associated British Ports, which received planning permission shortly before Scottish tidal energy firm Nova Innovation announced it will install 400kW FPV on an artificial lake in Cheshire.
Related:Elgin wins £500 million backing for 1GW UK solar and storage pipeline
Energy minister Michael Shanks commented on the report Bluefield commissioned, saying: “It’s time Britain stopped letting our solar potential float on by. 
“As this report shows, floating solar could generate the equivalent of around 11 gas power stations by 2040—cutting our dependence on volatile global gas markets we do not control.”
The report by CBI Economics found that, with the right policy environment, FPV could scale to 3.6GW by 2030, 18.3GW by 2040 and over 40GW by 2050. Bluefield noted that because reservoirs and similar managed water bodies are often located close to population centres, industrial clusters and AI growth zones, securing private-wire arrangements for high energy users to use energy generated by FPV plants can straightforward, sidestepping grid connection roadblocks.
Alongside the commercial and operational benefits for water companies and industrial users, CBI Economics also highlighted the environmental and system-level advantages that come with FPV.
These include improved drought resilience, because the floating arrays slow evaporation; reduced algal blooms; and, due to natural cooling from the water body, higher panel efficiency.
Aram Wood, appointed senior director of floating solar at Bluefield, said that to realise the potential of floating solar, “we need a policy framework that matches the urgency of the challenge,” but didn’t say what that framework might entail. 
Related:Octopus Energy enters Chinese energy market in JV with PCG Power
Floating solar projects are currently not eligible to bid for government support through the Contracts for Difference (CfD) scheme, which provides income certainty for renewable energy projects. 
One of the government’s Solar Roadmap actions is to address the viability of including FPV in the mechanism. 
Read more about:
Molly Green
Section Editor, Informa
Molly joined the team in 2024 and has led coverage on the UK sites. Now shifting to a more global view, Molly is interested in how legislation shapes market dynamics, covering the intersection of policy design, investment patterns, and energy transition pathways. 
Copyright © 2026 All rights reserved. Informa Markets, a trading division of Informa PLC.

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Indonesia’s PLN has launched a tender for a 1,225 MW solar project that will be spread across several regions of the country. The state-owned utility has not publicly announced a closing date.
Image: mz romadhoni/Unsplash
Indonesian state-owned electric utility company PLN has opened a tender for a solar project with a total capacity of 1,225 MW.
The Mentari Nusantara I solar power project will be developed across multiple regions of Indonesia, with 35 MW planned in Sumatra, 340 MW in Kalimantan, 600 MW in Java, 50 MW in Sulawesi, 80 MW in West Nusa Tenggara and 120 MW in Maluku and Papua.
The tender is being run through an integrated procurement scheme titled ‘Giga One’, which the utility explains promotes economies of scale and provides measurable project certainty for investors by bundling several projects into one package.
PLN kicked off the tender process last week (April 30). The utility has not yet published a closing date for the tender but has given the projects a targeted commercial operation date of 2029.
Suroso Isnandar, Director of Project Management and New and Renewable Energy at PLN, said the Mentari Nusantra project is a key initial driver in supporting the Indonesian government’s target of building 100 GW of solar.
Isnandar also said Giga One is “a new blueprint for renewable energy procurement in Indonesia and an important milestone in the national energy transition journey,” while advising that the procurement strategy will be replicated in future hydropower, wind power and battery energy storage system tenders.
Earlier this year, the Institute for Essential Services Reform and Indonesia’s Coordinating Ministry for Economic Affairs published a study exploring how Indonesia can work towards its 100 GW solar target, which targets 80 GW of decentralized, small-scale solar systems alongside 20 GW of centralized solar.
Indonesia surpassed 1 GW of solar capacity last year, with total capacity reaching 1.49 GW.
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According to data shared by the Department for Promotion of Industry and Internal Trade (DPIIT), total foreign direct investment (FDI) stood at ₹4,97,675.58 crore. Foreign direct investment into India’s solar energy sector reached ₹20,641.08 crore in 2025, equivalent to $2,377.82 million, accounting for a 4.16% share.
Moreover, taking a holistic view of India’s non-conventional energy sector reveals that FDI inflows in this segment rose from ₹31,188 crore in FY2023–24 to ₹33,797 crore in FY2024–25, marking a YoY growth of 8.37%.
However, despite being among the top 10 sectors in attracting foreign direct investment (FDI), inflows have declined to ₹22,020 crore, reflecting a sharp 34.84% drop compared to the previous year. Cumulatively, energy inflows have reached ₹1,81,978 crore. readers will be aware that the year saw a number of listings by solar firms to access domestic public markets, even as bank funding availability has also improved significantly. This has reduced the urgency to seek foreign funding in the sector considerably, other than in the developers category to an extent. 
In comparison, the broader non-conventional energy segment recorded FDI inflows of ₹6,267.20 crore ($723.20 million), while the power sector attracted ₹3,560.44 crore ($408.91 million). These investments are part of the total investment of ₹26,908.28 crore made in the non-conventional energy segment.
By contrast, traditional energy segments saw significantly lower inflows. Mining services received ₹46.50 crore ($5.33 million). Within the petroleum and natural gas sector, oil refinery investments stood at ₹8.60 crore ($0.99 million), while oil exploration attracted ₹1,006.72 crore ($115.17 million).
Compared to these segments, investment in petroleum and natural gas oil refinery was ₹8.60 crore, and in oil exploration it was ₹1,006.72 crore, taking the total investment in this segment to ₹2,527.51 crore.
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In this data center exclusive to All Access subscribers you’ll find a list of family-owned plastics-related companies ranked in order of number of years in business.

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100MW Munyati solar project gains momentum  Herald.co.zw
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Cattle graze under solar panels at Silicon Ranch’s Christiana Solar Ranch
Silicon Ranch, owner and operator of one of the nation’s largest fleets of solar facilities and a community-focused energy infrastructure company, officially launched its CattleTracker energy and cattle grazing technology April 30, 2026, on the Christiana Solar Ranch in Middle Tennessee. The landmark facility represents the first-ever commercial deployment of Silicon Ranch’s patented cattle-compatible agrivoltaics platform, designed to produce renewable energy and regenerative grazing outcomes on the same property.
Silicon Ranch funded, built and will own, operate and maintain the facility in Christiana, which is in the service territory of Middle Tennessee Electric (MTE). MTE is partnering with Silicon Ranch to purchase the power and environmental attributes generated by the facility—realizing savings on day one of operation—to benefit the more than 750,000 Tennesseans the cooperative serves across 11 counties. MTE is the largest electric cooperative in the Tennessee Valley Authority (TVA) region and the second largest in the United States.
Leadership from Silicon Ranch and MTE were joined by local officials, animal science and ecosystem researchers, as well as agricultural and conservation groups for a ribbon-cutting ceremony to dedicate the pioneering development and to celebrate the important milestone in the emerging field of agrivoltaics.
While grazing beef cattle under or near solar panels has been attempted in smaller research projects, both in the United States and abroad, the Christiana Solar Ranch will be the first project of its size in the world to co-locate a legitimate cattle ranching operation with a commercially viable solar energy infrastructure facility. This unique combination was made possible by a multi-year research effort led by Silicon Ranch that resulted in two patents being awarded to the company. Silicon Ranch Chief Technology Officer Nick de Vries served as Principal Investigator for the research and led the development of a novel tracking system that is designed and engineered to move into “grazing” mode to allow cattle to safely graze and move beneath the panels.
Christiana is a proof of concept for Nashville-based Silicon Ranch that underscores how a thoughtful approach to solar development and land use can provide solutions for the American cattle industry, similar to those it is already delivering for the American sheep industry through its nationally acclaimed Regenerative Energy agribusiness. And it can do so at wholesale energy pricing, ensuring that this patented innovation to support agriculture still delivers value to American energy ratepayers.
The CattleTracker project uses materials and technology Made in the USA. Silicon Ranch has a long-standing commitment—going back to its founding more than 15 years ago—to leverage its buying power to help bolster American manufacturing and onshore every element of the solar energy supply chain. This stimulus for regional economic development includes partnerships with First Solar, which recently opened a solar panel manufacturing plant in northern Alabama, and Nextpower, which manufactures the low-carbon steel components for the trackers used on the CattleTracker site at its Memphis, Tenn., manufacturing facility.
“CattleTracker was born at the intersection of American energy, American manufacturing, and American farming—all areas that are under tremendous pressure to evolve and grow in this country,” said Silicon Ranch co-founder and CEO Reagan Farr. “We have long believed that doing what’s right for our country, our grid, and our economy can also benefit our land, our animals, and our farmers.
“The innovation we celebrate today represents the tangible application of that belief and our commitment to make it possible, and I am confident it will yield many benefits for the surrounding community and wider region for a long time to come.”
“As a researcher, what’s most exciting about CattleTracker is that it brings rigor and real‑world validation to agrivoltaics at a commercial scale,” said Anna Clare Monlezun, founder of Graze LLC, La Dolce Vita Ranch, and a member of the CattleTracker research team. “At the Christiana Solar Farm, we’re demonstrating that thoughtfully designed solar infrastructure can support normal, healthy beef cattle behavior, align with animal welfare standards, and enhance land stewardship while also delivering reliable energy.
“This project provides an important foundation for continued transdisciplinary research into how regenerative grazing and energy production can successfully coexist.”
The CattleTracker research team has been performing field work since 2023 and has published its findings in academic journals. Led by Silicon Ranch, the world-class research team includes representatives from Graze, Quanterra Systems, Colorado State University and White Oak Pastures. Additional support was provided by an advisory committee that includes representatives from the National Laboratory of the Rockies, DNV, University of Georgia, Michigan State University, Standard Soil & Blue Nest Beef and the Solar Energy Industry Association.
Source: Silicon Ranch
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WorkForge Advisor and veteran food production executive Tim Cook (Marlen International, LINXIS Group, Shick Esteve, AMF Bakery Systems) will share findings from The Hidden Costs of Inconsistent Employee Development in Food Manufacturing – research that outlines ten common, measurable, and fixable cost drivers that quietly hit your P&L.
Join Tony Vacaro, Foods Industry Manager, and Emile Klein, Foods Market Strategy Manager at Air Products and Chemicals, Inc. , as they tackle key questions surrounding heat removal in food processing. 
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Cory Doctorow: Comrade Trump is the unwitting hero of a green revolution  The Nerve
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Friends of Sleeping Bear Dunes expands track chair program with solar power  9and10News.com
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Recognized As The Best Medium-Sized, Nondaily Newspaper In Illinois
Tuesday, May 5, 2026
GIBSON CITY — A California developer has withdrawn its application for a special-use permit for the construction and operation of a 2.25-megawatt solar farm on farmland just northeast of Gibson City.
Thirteen days after the city’s planning commission voted 6-1 to recommend the city council deny San Francisco-based ForeFront Power’s application, the company notified city officials of its request to withdraw it in a letter dated Monday, May 4.
The so-called “Ford Solar” project received pushback from several neighboring landowners during an April 21 hearing preceding the planning commission’s vote. The commission’s recommended denial of the application was expected to be considered by the council this month.
The project — owned by IL Solar Ford Project1 LLC, a company with the same listed address as ForeFront Power — was proposed to be built on a 23.42-acre triangular parcel of agriculturally zoned land at Ford County Road 600 East and Illinois 54 in Drummer Township.
No longer, though.
A map shows where a 2.25-megawatt solar farm is proposed to be built on farmland just northeast of Gibson City.
“Please accept this letter as the official withdrawal request from IL Solar Ford Project1 LLC of the Ford Solar (special-use permit) application for approval by the City of Gibson, Illinois,” stated the letter signed by Kristin Frooshani, vice president of ForeFront Power, and addressed to the planning commission’s chairman, Chase McCall, and deputy city clerk and advisor Jan Hall. “We request you please withdraw our request from any action by the Gibson City Council for the special-use permit application. We also request you send us verification that the request has been withdrawn and will not be presented to the Gibson City Council for any action.”
McCall said neighbors voiced a number of concerns about the project, including its proximity to homes and the potential for the solar panels to cause glare issues and groundwater contamination.
Among the seven commissioners present, McCall was the only one to vote in favor of the issuance of a permit for the project. McCall said he did so because of the project’s potential benefits to the community, including the temporary stimulation of the economy through the creation of jobs, an increase in tax revenue from the involved land for local taxing bodies, and the possibility that the city’s residents could apply to receive energy credits on their utility bills via an agreement with Ameren Illinois.
“From a planning commissioner’s perspective, I have to think about what’s in the best interest for Gibson City,” McCall said.
The city has zoning authority within 1 1/2 miles of its corporate limits.
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By Lokmat Times Desk | Updated: May 5, 2026 14:21 IST2026-05-05T14:21:49+5:302026-05-05T14:21:54+5:30
A fire broke out at the Reserve Bank of India (RBI) building in Delhi on Tuesday afternoon, May 5. After receiving the information, Delhi Fire Services (DFS), along with local police, reached the spot and began firefighting operations.
According to officials, the fire department received information about the incident at around 1.05 pm. The fire reportedly started in the MCV box of a solar panel installed at the building.

Delhi | Fire broke out in a solar panel box at Delhi's RBI building. Five fire tenders have rushed to the spot, and the fire has been brought under control. The fire broke out around 1:05 pm and was brought under control by 1:20 p.m: Delhi Fire Services

— ANI (@ANI) May 5, 2026

Delhi | Fire broke out in a solar panel box at Delhi's RBI building. Five fire tenders have rushed to the spot, and the fire has been brought under control. The fire broke out around 1:05 pm and was brought under control by 1:20 p.m: Delhi Fire Services
Also Read | Fire breaks out at RBI building in Delhi; five fire tenders rush to scene.
Around five fire tenders were rushed to the spot, and the blaze was brought under control by around 1.20 pm. No injuries were reported in the incident. Authorities are further assessing the cause of the fire and the extent of the damage.
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BAY MINETTE, Ala. (WALA) – Residents opposed to the development of large solar sites packed the Baldwin County Commission chamber Tuesday, demanding a halt to new solar development. They left without an answer.
The fight to keep solar out of north Baldwin County continued during the public comment section of the commission meeting. The push intensified after two more proposed solar farm sites were discovered in the Tensaw and Lottie areas. The concerns are the same as those with the current proposed Silicon Ranch project in the Stockton area.
“I want to encourage you to take…do the moratorium and take a look at the repercussions of what would happen,” one speaker said.
“There’s a real sense of urgency for this,” another said.
“What if there’s noncompliance? What if there’s a permit issue?” a third asked.
Residents seek time for environmental review
Those opposing solar development believe a moratorium could help answer their questions. The extra time would allow the county to hire an outside engineering firm to look at potential environmental conflicts and for county leaders to create guidelines for future development.
John Murphy, a Stockton resident who has helped spearhead the effort to slow down site development, said residents want answers soon.
“We want an answer, and something resolved as soon as possible because we are concerned about time and we’re concerned about everything that’s going on up there,” Murphy said. “We know that Silicon Ranch and these other ones that are trying to put in these solar sites, eleven thousand acres of solar sites, it’s not good for us.”
Diana Well Dean of River House Workshop said a closer look at the projects would be worthwhile.
“If they could do that, I think it would be…I mean, how’s it going to hurt? If they come up with the idea that it’s a great idea, at least they will have considered it,” Dean said.
Commissioners say they must follow legal process
Commissioners said they cannot act in haste.
“You have my word and I believe the word of everybody up here that we do not want this, and we are not incentivizing anything and we’re doing everything we can by what’s called the law,” Baldwin County Commissioner Billie Jo Underwood said.
Commission Chairman Jeb Ball said the commission is taking steps to ensure any action is legally sound.
“We have asked our attorney to do the due diligence on behalf of the Baldwin County Commission to do what any good steward would do before you make a knee jerk decision that could wind up in frivolous lawsuits that would cost the taxpayers’ dollars,” Ball said. “So, we asked our attorney to seek an AG’s opinion for it.”
The commission passed a resolution at the meeting to send a letter to Attorney General Steve Marshall’s office to get that opinion. No word on how long that will take. Silicon Ranch has yet to file any applications or other paperwork to move forward with the Stockton project.
Copyright 2026 WALA. All rights reserved.

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The Approved List of Models and Manufacturers (ALMM) is a regulatory framework administered by the Ministry of New and Renewable Energy (MNRE) that determines which solar photovoltaic (PV) modules, cells, and wind turbines qualify for use in government-backed and regulated projects across India. It assures that panels installed on rooftops and across utility-scale fields match their specifications, originate from the factories that claim to have produced them, and possess the durability to endure a 25-year operational life.
The Regulatory Foundation
MNRE issued the formal basis for this system through the “Approved Models and Manufacturers of Solar Photovoltaic Modules (Requirement for Compulsory Registration) Order, 2019,” dated 2 January 2019, referred to as the ALMM Order. The Order established two primary lists: List-I for solar PV modules and List-II for solar PV cells. The framework constructs a traceable chain from production line to project site by compelling manufacturers to register on a model-by-model, factory-by-factory basis and submit to audits and type testing. The first ALMM List-I was published on 10 March 2021, initially recording around 8.2 GW of enlisted capacity. By August 2025, it had expanded to include over 100 manufacturers with a combined declared annual capacity exceeding 100 GW.
Where ALMM Applies and the Key Exemption
ALMM compliance is mandatory for government projects, government-assisted projects, projects under government schemes and programmes, and open access and net-metering projects. The definition of “Government” encompasses central and state governments, public sector enterprises at both levels, and central and state autonomous bodies. Projects set up to sell electricity to government entities under Section 63 of the Electricity Act, 2003 also fall within its ambit. There is one carve-out: “behind-the-meter” solar plants used solely for captive consumption by a consumer or group of consumers are not required to comply with ALMM, either for modules or for cells.
How the Framework Has Evolved
In 2022, the scope of ALMM was extended to open access and net-metering installations. In early 2023, supply disruptions and COVID-era backlogs prompted MNRE to suspend ALMM enforceability for financial year 2023–24, exempting projects commissioned up to 31 March 2024. That suspension was lifted on 29 March 2024, reinstating mandatory compliance from 1 April 2024 without blanket exemptions.
The introduction of List-II for solar PV cells marks the most significant structural expansion. The first ALMM List-II was published on 31 July 2025 with nine manufacturers and a combined enlisted capacity exceeding 13 GW per year. An MNRE office memorandum dated 9 December 2024 declared that List-II compliance would become mandatory from 1 June 2026. Projects whose last date of bid submission fell on or before 9 December 2024 were exempted from List-II requirements regardless of their commissioning date. Projects bid after that date must comply, even if commissioned before June 2026. A further clarification in September 2025 confirmed that projects with a last bid submission date on or before 31 August 2025 are also exempt from List-II cell requirements, though they must still use modules drawn from List-I.
By the seventh revision of List-II, issued 30 April 2026, the list had grown to more than a dozen manufacturers across three cell technologies, P-Type Mono PERC, N-Type TOPCon, and HJT, with combined declared capacity above 30 GW annually. New entrants have included Waaree Energies, Reliance Industries, TP Solar, Tata Power Renewable Energy, and Fujiyama Power Systems. The geographic spread, concentrated initially in Telangana and Gujarat, has extended to Tamil Nadu, Karnataka, Himachal Pradesh, West Bengal, and Uttar Pradesh.
ALMM List-III Brings Wafers Into the Chain
MNRE has amended the ALMM Order to bring silicon wafers within the framework through a new List-III, with compliance required from 1 June 2028. The compliance chain will run across three tiers: wafers under List-III, cells under List-II, and modules under List-I. Module manufacturers will retain their List-I status only if the cells and wafers they use are themselves enlisted under ALMM. Non-compliance at any tier risks de-listing.
MNRE has specified that List-III will only be issued once at least three independently operating wafer manufacturing units exist, with no common ownership or control between them, and a combined annual manufacturing capacity of at least 15 GW. Eligible manufacturers must also possess matching ingot production capacity; standalone wafer slicing units without upstream ingot capability will not qualify. A cut-off date for List-III exemptions will be defined as seven days after the initial publication of ALMM List-III. Projects with bid submission deadlines on or before that date will be exempt from the wafer sourcing requirement regardless of when they are commissioned. Projects where either a power purchase agreement (PPA) has been signed or bids submitted before the cut-off date will retain that exemption even if engineering, procurement and construction (EPC) or module supply tenders are issued later.
The amendment outlines differentiated timelines by project type. Net-metering and open access projects commissioned before 1 June 2028 are exempt from wafer requirements, though List-I and List-II compliance still applies. For government-owned captive projects, those commissioned before 1 June 2026 need only use ALMM-listed modules; those commissioned between June 2026 and June 2028 must comply with both modules and cells; full three-tier compliance applies from June 2028 onward. Thin film module manufacturers with integrated facilities already listed under List-I are treated as compliant with List-II and List-III requirements. MNRE has also clarified that Domestic Content Requirement (DCR) provisions under schemes such as PM-KUSUM, PM Surya Ghar: Muft Bijli Yojana, and the CPSU Scheme Phase-II remain unchanged by the wafer amendment.
The Wind Side Transitions from RLMM to ALMM
A parallel framework has existed for wind energy since 2018. The Revised List of Models and Manufacturers (RLMM) required wind turbine generator (WTG) manufacturers to submit type certificates, design evaluations, and manufacturing system certificates before their turbines could be used in eligible projects. In July 2025, MNRE renamed RLMM to ALMM (Wind) and expanded its scope to require that critical components, specifically blades, towers, generators, gearboxes, and special bearings, be sourced from a forthcoming ALMM (Wind Turbine Components) list, abbreviated as ALMM-WTC. Manufacturers must also establish local research and development centres. Eligibility for concessional customs duty on wind turbine equipment is tied to RLMM and ALMM (Wind) compliance.
Wind Certification Under the New SOP
Standard operating procedures for enlistment under ALMM (Wind) and ALMM-WTC were issued in October 2025, replacing the earlier RLMM procedures. The standard operating procedure (SOP) establishes a two-tier system. ALMM (Wind) covers certified turbine models approved for deployment. ALMM-WTC covers approved manufacturers of the five major components: blades, towers, generators, gearboxes, and special bearings. Each turbine’s type certificate must name approved vendors for all five components. Component manufacturers can be enlisted under ALMM-WTC only if their products form part of an approved turbine model and their facilities pass a physical inspection by a government-appointed technical team. Inspections are conducted under ISO/IEC 17020 standards and verify production capacity, quality systems, and testing facilities; the base inspection fee is Rs 1.5 lakh plus applicable taxes. The SOP also requires that turbine data control and research centres be located in India. New turbine models receive a temporary exemption from the requirement to source all components exclusively from the ALMM-WTC list, capped at 800 MW or two years from enlistment, whichever comes first. Prototype testing of new turbines in India is now compulsory.
Wind Bearing Exemptions
The July 2025 ALMM (Wind) directive required that special bearings, specifically main bearings, yaw bearings, and pitch bearings, be sourced domestically for wind projects. Domestic availability of these components proved limited, and manufacturers made representations to that effect. MNRE responded with a revised office memorandum dated 16 February 2026, introducing a staggered exemption framework. For projects where bidding was completed before 31 July 2025, main bearings are exempted from the domestic sourcing requirement. This exemption also applies to all projects bid or to be bid up to 31 July 2027, a two-year window subject to review based on how domestic supply develops. For wind projects scheduled for commissioning within 18 months of 31 July 2025 under captive, open access, commercial and industrial (C&I), or third-party sale arrangements, yaw and pitch bearings have been granted a one-year extension to 31 January 2028, and main bearings an exemption extending to 31 January 2029, again subject to review. All other provisions of the July 2025 office memorandum remain in force.
Intersecting Policy Instruments
Bureau of Indian Standards (BIS) certification is a prerequisite for ALMM registration; a manufacturer without BIS certification cannot be listed under either framework. The Production Linked Incentive (PLI) Scheme for high-efficiency solar PV modules, launched in two tranches in April 2021 and September 2022, has backed approximately 48 GW of domestic manufacturing capacity. On the import side, Basic Customs Duty (BCD) of 40% on modules and 25% on cells, in effect since April 2022, raises the cost of foreign equipment. Even if customs duty has been paid, non-ALMM-listed modules and cells cannot be used in utility-scale or government-backed projects. Goods and Services Tax (GST) on solar modules, cells, and WTGs was reduced from 12% to 5% effective 22 September 2025. Government schemes such as PM-KUSUM and the rooftop solar programme explicitly require ALMM-listed equipment in their guidelines and tender conditions. Bidders must specify the make and model of modules they intend to use, and only listed models are accepted.
Consequences of Non-Compliance
Non-compliance can take several forms: procuring or installing unlisted modules or WTGs, deploying unlisted models or an altered bill of materials from a listed manufacturer, submitting falsified documentation, mixing compliant and non-compliant components, or continuing to use equipment from a manufacturer that has been suspended or de-listed. Financial incentives and subsidies, including viability gap funding, are conditional on proof of ALMM-listed equipment, and non-compliant projects lose access to these. Under DCR conditions embedded in many MNRE schemes, violations can lead to criminal action, blacklisting for ten years, and forfeiture of bank guarantees. The Bharatiya Nyaya Sanhita, 2023 (BNS) adds a further layer of penal exposure: misrepresenting the origin, certification, or ALMM status of solar modules or cells to obtain government project eligibility or subsidies can attract liability under Section 316, which covers cheating by deceit. Administrative consequences follow a standard escalation path: show-cause notice, blacklisting, contract termination, and financial recovery including clawback of disbursed subsidies, pursued in parallel with any penal action.
The Bottom Line
ALMM determines which manufacturers gain access to India’s publicly driven renewable energy market. Those that pass MNRE’s scrutiny are eligible; those that do not, whether domestic or foreign, are not. As the framework extends from modules to cells and wafers, and as the wind side builds out a parallel component-level approval system, the supply chain being shaped by ALMM becomes more integrated, more traceable, and more demanding with each revision.
The Comptroller and Auditor General of India (CAG) has reported major deficiencies in the planning, execution, financial management, and monitoring of the Deen Dayal Upadhyaya Gram Jyoti Yojana (DDUGJY) and the Pradhan Mantri Sahaj Bijli Har Ghar Yojana (SAUBHAGYA).   The Government of India launched the schemes to improve rural electricity access and reliability. The Deen…
Read More CAG flags planning and execution gaps in DDUGJY and SAUBHAGYA schemes
  In nuclear power generation, not all shutdowns are emergencies. Many are planned well in advance for regular refuelling, equipment maintenance, or regulatory inspections. These scheduled outages are an essential part of operating a safe and efficient nuclear power plant. But how long do they take? And how do the timelines compare across global reactors…
Read More How Long Do Scheduled Nuclear Reactor Shutdowns Take?
India will require cumulative power sector investment of $14.23 trillion (approximately Rs 1,200 lakh crore) and up to 5.92 million hectares of land by 2070 to achieve net-zero emissions, according to reports released by NITI Aayog. The studies project a sharp rise in electricity demand, large-scale renewable expansion, and significant social, land, water, and workforce…
Read More NITI Aayog: $14.23 trillion power investment and 5.92 million hectares needed for net zero
  India has come a long way in its energy journey since its independence. According to the Central Electricity Authority (CEA), total power generation capacity (utilities and non-utilities) surged from 1,362 MW (1.36 GW) in 1947 to 521.31 GW by March 2024. Per capita electricity consumption rose from 16.3 kWh in 1947 to 1,395 kWh…
Read More Nuclear Power in India: Facts Over Fear
The International Energy Agency’s Electricity 2026 report positions electricity as the defining energy vector of the coming decade. Demand growth is accelerating globally, driven by electrification, digitalisation and climate policy. Within this context, India is one of the largest contributors to global electricity demand growth. India’s power system is expanding at a scale and speed…
Read More Electricity 2026: India’s demand surge, grid strain, and shifting power mix
A transformer works on the principle of electromagnetic induction. It transfers power from one circuit to another at the same frequency but with a change in voltage. The device has a steel core, usually laminated to reduce losses, which provides a path for magnetic flux. It has two windings: the primary, connected to the power…
Read More Transformers: industry growth, demand drivers, and market outlook
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India's rooftop solar installations nearly doubled in FY26, with the PM Surya Ghar Yojana benefiting over 2.1 million homes. However, growth is heavily concentrated in Maharashtra, Gujarat, and Uttar Pradesh (60% of installations). This uneven surge highlights policy conflicts, like competition with free state power, administrative hurdles, and funding gaps, which slow wider, fairer adoption and challenge India's renewable energy goals.
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India's renewable energy drive saw a sharp rise in rooftop solar installations in the fiscal year ending March 2026, largely thanks to the PM Surya Ghar Muft Bijli Yojana. Around 2.12 million households installed rooftop solar systems, nearly double the 1.08 million from the year before. This brings the total installed capacity to over 3.2 million households. The scheme, launched in February 2024, aims for one crore (10 million) installations and projects one trillion units of renewable electricity, potentially cutting CO2 by 720 million tonnes. Yet, this impressive national growth hides significant regional differences, showing that consistent progress across the country is still hard to achieve. By the end of 2025, India's total rooftop solar capacity neared 20.8 GW.
The fact that installations are concentrated in Maharashtra, Gujarat, and Uttar Pradesh—making up 60% of all household installations in FY26—points to critical policy issues. Maharashtra had over 515,000 installations (a twofold increase), Uttar Pradesh saw a fourfold jump to over 434,000, and Gujarat added over 319,000. This difference is strongly tied to state policies. For example, states like Gujarat, which don't offer free electricity, have much higher rooftop solar adoption. In contrast, states like Punjab, which provide 300 units of free power, showed the slowest growth among major states with only 6,460 installations. This highlights a policy conflict: state subsidies for regular electricity use may discourage people from adopting solar power, creating a paradox for national energy goals.
Beyond state policies, administrative issues, funding gaps, and low consumer awareness remain obstacles. While millions of applications are processed via the national portal, many don't lead to installations, showing underlying problems. The upfront cost, even with subsidies, is still too high for many middle-class families, and banks offer limited, risk-averse financing options. Poor installation quality and inconsistent after-sales service also hurt consumer trust and enthusiasm in many areas.
The growth in rooftop solar happens as India's overall renewable energy capacity expands rapidly. By April 2026, India had already exceeded its 2030 goal for non-fossil fuel power, with these sources making up over 50% of its total installed capacity (around 283 GW). India aims for 500 GW of non-fossil capacity by 2030. Solar power is the main driver, surpassing 110 GW in capacity by January 2026. Although large-scale solar projects add the most capacity, the residential rooftop sector is seeing strong growth thanks to the PM Surya Ghar program, accounting for about 76% of total rooftop additions in 2025. However, maintaining this pace requires tackling the uneven adoption patterns that could create unequal energy access and costs.
Despite headline growth numbers, India's rooftop solar expansion faces several risks. The stark regional differences in adoption could worsen energy equity gaps. This might lead to a situation where some people save money on electricity while others, who can't install solar, face higher tariffs because Distribution Companies (Discoms) lose revenue. This 'utility death spiral' is a concern as wealthier households use less grid power. The focus on a few states might also show a bias towards cities or areas with stronger administrative support, possibly ignoring rural or less developed regions. Additionally, delayed subsidy payments, poor installer quality control, and low consumer awareness in smaller cities continue to reduce trust and slow adoption. The financial struggles of Discoms could worsen if rooftop solar leads to significant revenue loss without higher electricity prices or investments in grid upgrades.
Analysts expect rooftop solar installations to keep growing in 2026, led by the residential sector and backed by steady demand from commercial and industrial areas. However, expected rises in solar panel costs and stricter rules could increase system prices, possibly slowing demand. Adding energy storage is also becoming key for future solar projects, helping to solve grid stability issues. The success of the PM Surya Ghar Yojana, and India's wider renewable energy targets, will depend on closing the adoption gap between states, ensuring fair distribution of benefits, and overcoming ongoing funding and administrative problems.
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ZBA vote was 4-0-1 plus 2 absences
By Randy Pierce • Without a single vote of support and amid objections from residents, the Madison County Zoning Board of Appeals (ZBA) on April 28, voted against the issuance of a special-use permit that would allow for the development of a five-megawatt (MW) commercial solar energy facility at 2951 Old Troy Road in unincorporated Glen Carbon.
The location is south of the Savannah Crossing Subdivision and south of the intersection of Madison County Transit’s Glen Carbon Heritage and Goshen trails. 
The permit request from Trentino Solar LLC of Lafayette, Louisiana on behalf of the Lorraine M. Keller Trust, required per county zoning regulations for the agriculture zoned district, was next to be considered by the county board building and zoning committee, scheduled to meet on May 5, before advancing to the full county board on May 20, for a final decision unless it is held up for some reason.
Chairman Sharon Sherrill voted against the proposal along with George Ellis, Mary Goode and Joe Pattan while Bruce Riedle abstained with Don Metzler and Curtis Stephens absent from the meeting.
Jen Hurley, the county’s zoning coordinator, explained that the proposal meets requirements for a project like this including a minimum of 150 feet for setbacks, a perimeter fence of at least six feet in height and masking.
She additionally referenced five letters of opposition, four of them consisting of the same basic wording concerning the sentiments of residents in that area including Jason and Amanda Gillihan of 2947 Old Troy Road, Adam and Ashleigh Rockwell of 2949 Old Troy Road, Joan Lingle of 42 Leon Drive and Robert and Angela Henshaw of 141 Oaklawn Drive.
That letter alleges that the applicants failed “to unequivocally demonstrate significant economic and energy benefits to Madison County, while lending significant concerns to how it will affect the comfort and convenience of the public and surrounding neighborhood.”
Yet another letter from the Henshaws shared by Hurley said the couple, who own property adjacent to the proposed solar facility site, expressed that they are worried about water runoff there and downstream impacts.
The 95-acre property considered for this “isn’t just a field, it’s the starting point for a 14-mile creek (Judys Branch Creek) system our entire community relies on for drainage,” the Henshaw correspondence stated.
Their description said the “rolling farmland acts as a giant sponge” which would be negatively impacted by the Trentino (and Ironwood Renewables) installation of 467 solar arrays, metal posts and presumed concrete footings while heavy machinery used during the construction would pack down the soil, making it tighter and less capable of water absorption.
They further alleged rainwater would not soak into the ground when running off the panels and lead to a high quantity of water heading into nearby creeks and streams plus Horseshoe Lake, causing the banks to erode and crumble while additionally citing the potential for disruption of the ecosystem supporting wildlife and natural growth.
Darrel Keller, a trustee connected with the property ownership, wrote that the group he is part of feels the project is “a responsible and beneficial use of the land” in that it represents low impact while preserving open space and avoiding dense residential or commercial development that could generate more traffic, noise and deterioration of infrastructure such as roads.
Along with stating the project, which would be northeast of Judys Branch Creek, will lead to less intensive outcomes than other possible uses, Keller cited its representatives’ professionalism, transparency and level of respect while calling attention to what he feels is the benefits of increased tax revenue and responsible energy development for the county.
Among those present at the ZBA hearing who spoke about the project was Glen Carbon Mayor Bob Marcus who said the project fails to comply with the comprehensive plan for the area where it will be located and will have a negative impact.
An attorney representing the development team, Seth Uphoff, who had spoken earlier, asked to “cross-examine” Marcus but was not allowed to by Chairman Sherrill, because he had an opportunity to speak earlier, then requested that the meeting record reflect this.
James Craney, who said he owns adjoining property, said the project is being misrepresented in that it will not benefit neighbors but instead lead to the selling of shares to any Ameren customer who will then get a utility bill reduction. 
Another adjoining property owner, Anna Slattery, referenced what she said was the Interstate 55 Corridor Plan which this project fails to comply with, remarked that residential use could generate more tax income and expressed concern regarding the bike trail in this area.
    Next, Alan Black, who lives nearby, offered support to the other statements of opposition and said the project will only benefit a “select few” outside of the landowner and solar company. 
He went on to cite issues with historical artifacts on the site, anticipated drainage problems, resultant property value reductions plus animals and plants that could be negatively affected.
The loss of farmable acreage in the county was brought up by Randy Lingle Jr., whose family owns property to the south, while he also stated he was under the impression, among his other concerns, future development of any kind around the MCT bike trails there was prohibited. 
Michael Keith, a civil engineer from a firm named Atwell, located in Naperville near Chicago, told the ZBA that the project plans comply with the county’s stormwater management regulations and that construction would begin next spring and take between nine and 12 months.
Hurley pointed out that the applicant interests had submitted communications from the Illinois Department of Natural Resources and the United States Department of the Interior Fish and Wildlife Service regarding the potential impact on wildlife habitat and living animal species in the vicinity of the proposed project.
Written information provided by Keith Morel on behalf of the Trentino/Ironwood LLCs, noting this team has 35 years of experience developing such projects, including 10 to 15 projected in Illinois, explained the facility’s fenced area would total 27 acres of the 95+ of the entire parcel and that this location was chosen on the basis of the need for electricity in the local vicinity, its proximity to relevant connections, accessibility from nearby roads, characteristics of the land, interest of the property owner and the existing zoning.
Morel’s letter also stressed that compared to the $2,615 (in 2024) generated by the property in tax revenue, the site would produce $26,903 during its first year, providing support to entities such as local school districts along with powering 1,150 single-family homes with an expected annual output of 11.4 million kilowatt hours, saving Ameren customers 20% on their bills.
Still other positives mentioned by Morel were jobs; an estimated 24 positions during construction and those for ongoing maintenance upon completion plus the increased customer traffic for local business that would result.
Uphoff, when granted a chance for rebuttal by Sherrill after all the other comments were taken, said all the required environmental studies completed reflect the required standards being met and that the solar panels would be hidden from the general view of the public behind (west of ) the Goshen Trail. Also, in response to concerns about toxins, he said that the panels would contain only race amounts of certain metals and lead-free solder.
 

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Bangladesh’s solar photovoltaic capacity may rise from 1.3 GW in 2025 to around 8.5 GW by 2035, boosted by rooftop installations in industry, GlobalData says.
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Published 4:30 pm Tuesday, May 5, 2026
By Jeff Moore
The Prince Edward County Planning Commission has recommended approval of a proposed shared solar project, but not before a resident raised concerns about traffic, property values and environmental impacts during a public hearing.
The commission voted unanimously to recommend a special use permit for the Prince Edward Solar 2 LLC project, a 3.8-megawatt facility planned for property owned by Andrew Elder. The recommendation now moves to the county board of supervisors for final consideration.
The project would be the developer Jesse Dimond’s second in the county and part of a growing number of small-scale solar installations in the area. Dimond is senior project developer with New Energy Equity.
“This is my second project in Prince Edward County,” Dimond told the commission. “We’ve done over 500 megawatts of projects. We’ve invested over $600 million during those projects.”
The proposed facility would operate as a “shared solar” site — a model that allows residents to subscribe and receive reduced electricity costs. The developer said participants typically see about 10% savings.
“It’s just savings,” Dimond said. “I don’t have to subscribe to it in the sense that there isn’t, like, a monthly fee that I pay.”
SITE DESIGN AND OPERATIONS
The project would use solar arrays that track the sun, rotating throughout the day to maximize energy production. The developer said the site’s natural features — including tree lines and topography — would help limit visibility.
“This is a great location,” Dimond said, noting that “we don’t expect any view shed from any neighbors or passerby.”
He also emphasized that the project would have minimal long-term impact on the land, with plans for eventual restoration.
“At the end of this, after the soil has had its time to regenerate … it can go right back into farming,” Dimond said.
Noise and environmental concerns, often raised with solar projects, were also addressed.
“It’s not gonna bother other people,” he said. “You’re going to get dissipated within 100 feet to a noise level that is probably quieter than I speak.”
On environmental safety, Dimond said solar panels pose little risk even if damaged.
“They don’t leak,” he later reiterated during the meeting, comparing panels to “a computer chip.”
RESIDENT’S CONCERNS
Only one resident spoke during the public hearing, but his concerns were wide-ranging.
“I don’t want the solar form,” said Craig Moore, whose home is adjacent to the proposed site.
Moore said visibility would remain an issue despite planned buffers. “The solar panels light up like their mirrors,” he said. “So I see it any how.”
He also expressed concern about declining property values and potential environmental risks.
“If one of those panels gets broken and it spills, that’s a hazardous spill,” he said.
Moore pointed to existing issues with traffic related to a nearby solar project, describing frequent delivery trucks mistakenly entering his property.
“I get traffic, tractor trailers that come down my drive, turn around on my front lawn and go back out,” he said.
He recounted one incident in which a truck damaged his wife’s car and others involving drivers unloading materials in his yard.
“I don’t want to put up with this again,” Moore said. “It’s farm land. Let it be farmland.”
APPLICANT, STAFF RESPONSE
Dimond acknowledged the concerns and said he would work to address them, particularly regarding traffic and signage.
“I genuinely hear you,” he said, adding he would contact other project operators to improve directions for delivery drivers.
County staff also noted they had not received formal reports of incidents but said they would follow up.
“We’ll do a site visit and have a discussion with the general contractor on the other project,” Director of Planning and Community Development Robert Love said.
CONDITIONS ADDED
In response to concerns, the commission discussed and added several conditions to the project recommendation, including:
• Enhanced signage to direct construction traffic
• Defined delivery hours, generally during business hours
• Designated laydown and turnaround areas for trucks
• Expanded setbacks and buffers, including up to 150 feet on some sides
• Additional guidance on vegetation to improve screening
• The developer agreed to the conditions.
“Absolutely, yes,” Dimond said when asked if he would accept them.
He also agreed to additional provisions, including clearer site markings and potential limits on after-hours activity.
Commission members also discussed evolving standards for solar projects, including stricter soil testing requirements and more frequent reviews of decommissioning costs.
LOOKING AHEAD
Property owner Andrew Elder told the commission the project is part of long-term planning for his family.
“Basically, I’m just looking into the future,” he said. “My family, kids, insurances, taxes.”
Despite opposition from at least one neighbor, the commission ultimately supported the project with added safeguards.
The board of supervisors will hold its own public hearing during its meeting at 7:30 p.m., Tuesday, May 12 before making a final decision.

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The 1.6 MW Nexus pilot project in California has demonstrated that solar panels installed over irrigation canals can significantly reduce water evaporation and algae growth by 85%, while also showing operational efficiency.
Image: Solar Aquagrid

In September 2025, the Nexus pilot project in California, United States, was completed. The 1.6 MW solar installation is located on canals operated by the Turlock Irrigation District (TID) and was developed through a public-private partnership between the California Department of Water Resources, TID, Solar AquaGrid, and the University of California (UC), Merced. The project aimed to generate empirical data under real-world operating conditions.
Launched in 2022, the pilot evaluated the technical and operational feasibility of deploying PV systems on active irrigation canals. The concept enables dual use of existing infrastructure: clean electricity generation alongside reduced water evaporation and minimized land use – an approach particularly relevant in agricultural regions such as California’s Central Valley.
The project monitors key performance indicators including electricity generation, evaporation losses, water quality, aquatic vegetation growth, and canal maintenance requirements. After one irrigation season, initial results indicate measurable benefits for the water sector. Canal sections covered with PV modules showed reduced evaporation and lower aquatic weed proliferation, which may translate into reduced operating costs.
Specifically, continuous measurements over a full irrigation season recorded evaporation reductions of 50-70% beneath the solar arrays and an 85% decrease in algae growth, a result that could yield operational efficiencies in canal management. These findings are consistent with earlier research by UC Merced, which highlighted the potential of canal-based solar systems to improve water-use efficiency in open-channel infrastructure.
From a technical perspective, the project also serves as a testbed for multiple design configurations. These include large-span structures over wide canals, smaller systems on narrower channels, vertical installations along canal banks, and early-stage retractable prototypes. As previously reported by pv magazine, a battery energy storage system (BESS) was also deployed at the narrowest site, using 75 kW iron-flow batteries supplied by US manufacturer ESS.
This range of configurations is intended to assess system adaptability under varying hydraulic and structural conditions.
Project developers note that the scalability potential is significant, given California’s extensive canal network. A UC study estimates that covering approximately 4,000 km of canals could save 63 billion gallons of water annually, equivalent to irrigating 50,000 acres (20,234 hectares) of farmland or meeting the residential water demand of more than 2 million people. Beyond water savings, improved water quality through reduced vegetative growth is also of interest to TID.

Author:  Pilar Sánchez Molina
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The 120 MW Doornhoek solar photovoltaic (PV) project in the North West has entered operation, adding new generation capacity to South Africa’s grid under the Renewable Energy Independent Power Producer Procurement Programme (REIPPPP). 
Sineng Electric has supplied and commissioned inverter technology for the project, including 19 central inverter units, which convert solar-generated electricity into grid-compatible power. 
The company says the system is designed to support stable output and efficient performance under local grid conditions. 
The Doornhoek project forms part of the REIPPPP, a key mechanism for adding privately developed generation capacity to the grid and diversifying South Africa’s coal-dominated energy mix. 
Sineng Electric says the plant is expected to contribute hundreds of gigawatt hours of electricity annually to support national supply and reduce carbon emissions. 
The project adds to a growing pipeline of renewable capacity being connected to the grid. According to Sineng Electric, such developments aim to support supply and investment in new generation. 

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Australia’s rooftop solar market climbed by 31% in the past month with the latest data revealing that a record 442 MW of small-scale PV capacity was installed across the country in April 2026.
Image: Western Power

From pv magazine Australia
Australian households and businesses installed more rooftop solar last month than in any other month on record with new data from solar and storage market analyst SunWiz showing 442 MW of sub-100 kW rooftop PV capacity was registered nationwide in April 2026.
This marked a 31% increase on the 341 MW registered across the country in March and is almost double the 225 MW of new capacity registered in April 2025.
“We have now reached the strongest month in the history of STC (small-scale technology certificates),” SunWiz Managing Director Warwick Johnston said, adding that the market is now running 35% ahead of the same point in 2025.

Johnston said the surge in solar registrations was largely a byproduct of changes to the federal government’s Cheaper Home Batteries Program, which has supported the installation of more than 350,000 small-scale battery energy storage systems over the past 10 months.
Changes to the rebate scheme, that provides discounts of up to 30% on the upfront cost of installing small-scale battery systems alongside new or existing rooftop solar, were introduced on 1 May 2026. In the wake of the changes, systems installed through the program will continue to receive the full discount on the first 14 kWh of usable capacity, while 14-20 kWh batteries will get 60% of the discount and 28-50 kWh batteries will get 15% of the rebate.
Johnstone said the adjustments to the battery rebate scheme had “triggered a surge in battery demand with a meaningful flow-on effect to solar.”
“The rebate cut sent households scrambling for large-format (40–50 kWh) batteries, and the bigger solar arrays needed to run them followed, turning the Cheaper Home Battery Program into a multiplier well beyond its original scope,” he said.

Every state posted growth in rooftop solar installations in April with 143 MW of new capacity registered in New South Wales alone, up 35% on the previous month.
The Australian Capital Territory reported a 62% increase while Queensland delivered a 36% month-on-month increase.
SunWiz said most rooftop PV segments had recorded growth over the month with the 20-30 kW segment the standout, delivering almost double the installed capacity compared to March, up 98%.
The 15-20 kW segment increased by 61% while the 30-50 kW segment recorded growth of 45%. The 3-6 kW and 6-8 kW segments showed minor dips in month-on-month capacity growth.
The growth in the larger segments saw the national average system size bump up to 11.35 kW.
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Home improvement / Energy saving / Solar
Checked for accuracy by our qualified fact-checkers and verifiers. Find out more about fact-checking at CHOICE
Australia’s residential solar industry is big, and getting bigger. As of December 2024, there were more than four million rooftop solar photovoltaic (PV) systems installed across Australia.
On this page:
It’s a notable milestone, but the boom has also seen a rise in complaints about solar companies. In recent years, we’ve seen a surge in members needing help with problems with their solar PV system.
Meanwhile, the Clean Energy Regulator has conducted inspections of residential solar installations that have shown that a small but significant number are underperforming or not configured correctly, and some are actually unsafe.
With the federal government’s new rebate offering big discounts on home batteries, it’s likely both customer demand and complaints about dodgy installers will continue to rise.
Here’s our easy guide to avoiding shady deals and getting a quality system at a fair price.
_{Note: In the image above, a person is walking on solar panels. This isn’t recommended as it can damage the panels.}
The good news for consumers is that the solar industry has more accreditation than ever to protect consumers and maintain standards. The trick is knowing what accreditation to ask for and where you can check it.
When you’re buying and installing a solar PV array, it’s likely you’ll be dealing with:
In some cases, one person (for example a local electrician who specialises in solar installations) can cover all four roles. It’s also not unusual for larger retailers to secure the sale and contract, and then subcontract out the installation.
The ACCC authorised the NETCC program as a way for solar PV, battery storage and other new energy tech businesses to demonstrate commitment to responsible practices, including sales and marketing, the installation itself and warranty support.

The program is intended to improve consumer protection standards in the solar and storage industry. 

NETCC Approved Sellers commit to a high standard of quality in:
Visit the NETCC website to find approved sellers in your area.
Many solar installers have opted to not go for NETCC approval, but they must still be accredited. The accreditation body for solar installers is Solar Accreditation Australia (SAA). On their website, you can search for your installer by name or accreditation number to ensure they are current. 
The Clean Energy Council (CEC) is the accreditation body for solar panel system components, and is funded by industry.
The CEC also maintains a register of approved panels (modules), inverters and batteries that meet Australian standards. It’s highly unlikely that a reputable installer would be using unapproved components, but if in doubt, you should check that the components for the system quoted are clearly specified by make, size and model, and are CEC-approved.
If the components, the designer or the installer are not accredited, you won’t receive the government’s solar panel rebate or the newer home battery rebate. 
CHOICE has partnered with SolarQuotes to create the CHOICE Solar Estimator. It’s free to use, and will help you estimate a suitable solar PV system for your home, including the ability to add solar battery storage.

If you want to, it will also connect you with reputable installers in your local area for high-quality, obligation-free quotes.
Note: While CHOICE makes money if you buy through SolarQuotes, 100% of it goes straight back into our nonprofit mission.
As with any major investment, you should get at least three quotes for your solar PV system and research each company’s history and reputation before signing anything. Here’s what you need to find out:
Finn Peacock, founder of solar company SolarQuotes, says that choosing solar systems on price alone is a recipe for disaster.
“The solar business is a challenging one, and margins usually don’t allow for deep discounts. We recommend calling around for a few quotes to establish a base cost for battery storage and installation.”
Some of the problems with cheap quotes that he’s seen include:
Our solar panel buying guide explains current prices and points to consider when buying a solar panel system.
Australian solar retailers will often talk about ‘tier one’ ranking for solar panels, but tier rankings are designed for commercial solar investors rather the buying public and are not usually publicly available.
The tier ranking comes from Bloomberg New Energy Finance industry research and ranks the company on how big it is, how many solar farm projects its panels have been used in and how many financial institutions have invested in these panels.
While it’s reassuring that a solar panel has qualified for ‘tier one’ status, it’s not a guarantee that it’s a premium product.
You can ask the solar retailer to produce a certificate or other independent verification to prove they really are ‘tier one’.
These should cover parts and labour for the installation work of the system (cabling, connections and so on), and preferably all the components (panels, inverter, racks etc) for at least five years.

It should also cover any issues that arise from the installation, such as a leaking roof. Check carefully as to what your installer’s warranty actually covers. 
For solar panels, these generally last for 25 years and guarantee that solar panels will produce a minimum percentage of their rated capacity, which slowly reduces as the panels degrade over time.
These cover physical and electrical problems in the components that either cause it to fail or under perform. Examples include moisture ingress, breakage of panel glass, frame or back-sheet, and electrical failures.

Each component will come with its own individual warranty. Home batteries and inverters typically have 10-year warranties, while 25 years is very common for solar panels these days. 
It’s fair to wonder whether the manufacturer would even still be around in 25 years or more, but at least these longer warranties are an indication of confidence in the product.
Some warranties cover the removal of the PV panel as well as the replacement, while others provide the replacement modules but not the reinstallation.
Some warranties cover the removal of the PV panel as well as the replacement
However, note that replacement of solar panels under the product warranty is pretty rare, partly because panels are generally reliable, but also because it can be hard for a consumer to prove that panel failure after several years is due to a manufacturing fault. 
See our solar panel buying guide for more information.

When you sign a contract that has arisen from an unsolicited sale, a 10-day cooling-off period applies in which you can exit the deal.
Some suppliers may offer a 10-day cooling-off period in their terms, regardless of whether it was an unsolicited sale or not. Be sure to check.
The Australian Consumer Law (ACL) offers protection for you if there are any problems with your solar PV system, whether that’s with the service provided by the installer, or the components of the system.
The provision and installation of the solar PV system is a service by the solar company, and as such, according to the ACL it must:
If you have a complaint about the service provided, see our guide to resolving issues with bad service under the ACL.
The components of the system (including the panels, panel support racks, inverter, and electrical components) are covered by the ACL, just like any other product or appliance that you buy. Under the ACL, the components must be:
If the product fails to meet either of these conditions, you should be able to claim a repair, refund or replacement, depending on the nature of the problem.
See our guide to your rights with a faulty product for more advice on how to use the ACL to address any complaints with the installer or manufacturer.
Chris Barnes is a Senior Project Officer. He manages the product reviews that are done outside of CHOICE with external labs or data sources. This includes solar panels, electric heaters, air purifiers and detergents. Chris also manages our testing services through our commercial arm, Test Research, and he is CHOICE’s NATA authorised representative for our lab’s formal accreditations. Chris is involved with the standards committee for air conditioners. And he works with government and industry in areas such as product safety and regulation. In over 20 years at CHOICE, Chris has managed lab teams for a wide range of products, including children’s products, kitchen appliances, laundry appliances, garden power tools and more. Chris has a Science degree from the University of Sydney. LinkedIn
Chris Barnes is a Senior Project Officer. He manages the product reviews that are done outside of CHOICE with external labs or data sources. This includes solar panels, electric heaters, air purifiers and detergents. Chris also manages our testing services through our commercial arm, Test Research, and he is CHOICE’s NATA authorised representative for our lab’s formal accreditations. Chris is involved with the standards committee for air conditioners. And he works with government and industry in areas such as product safety and regulation. In over 20 years at CHOICE, Chris has managed lab teams for a wide range of products, including children’s products, kitchen appliances, laundry appliances, garden power tools and more. Chris has a Science degree from the University of Sydney. LinkedIn
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AMPIN Energy Commissions 500 MWp Wind–Solar Hybrid Project In Rajasthan, Strengthening India’s Clean Energy Push  SolarQuarter
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EDP Renewables North America and Meta have signed a 250 MW power purchase agreement for the Cypress Knee solar project in Arkansas, bringing their renewable energy collaboration to 545 MW.
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The Ann Arbor Sustainable Energy Utility will use locally sited solar, batteries and other resources to improve reliability and lower costs for subscribers, city officials say.
The homes participating in the pilot program are located in Ann Arbor’s Bryant neighborhood, where A2SEU held a March meeting seeking residents willing to become its first customers.
Bryant has more energy-burdened residents than Ann Arbor as a whole, with some locals spending upwards of one-third of their household income on utility bills, FranklinWH said. Neighborhood median income is well below the citywide average, according to local media outlet MLive.
At the meeting, Jordan Larson, engagement innovator with the city of Ann Arbor’s Office of Sustainability and Innovations, showed a chart illustrating how enrolled homes would self-consume some of the power generated by their panels and store the rest in batteries for discharge during the evening and overnight hours.
“All of the work in this project is focused on reducing total energy costs,” Larson said.
In 2024, nearly 80% of Ann Arbor voters approved a referendum to create a city-owned utility that would help accelerate the city’s clean energy goals and boost local resilience. The Bryant solar-plus-storage pilot is the first step toward a future that A2SEU says could feature microgrids, geothermal heating and cooling networks, and energy justice initiatives for the roughly 125,000 inhabitants of the university town 40 miles west of Detroit.
“Unlike a traditional utility, we are only going to offer renewable energy products, including solar and geothermal that will come later to this neighborhood and hopefully all around the city,” Shoshannah Lenski, A2SEU’s executive director, said at the March meeting.
A spokesperson for DTE Energy, the investor-owned utility that serves Ann Arbor, Detroit and surrounding communities, said it supports A2SEU’s sustainability goals in a statement comparing the municipal program to DTE’s own voluntary clean energy program.
“When coupled with DTE’s planned investments in clean energy, these voluntary, fee-based programs help accelerate economy-wide decarbonization while maintaining reliability and affordability,” Ryan Lowry, the spokesperson, said in an email.
A2SEU says energy storage will help its subscribers ride through power outages and — along with other onsite power generation — boost overall system reliability by “[minimizing] the need for distribution systems (e.g., poles and wires), which are currently the most vulnerable part of the existing energy system.”
A 2025 report from the Citizens Utility Board of Michigan, a utility watchdog group, found Michigan’s power grid experienced longer-duration outages over the past five years than all but a handful of other states. DTE is spending billions to upgrade its distribution grid and says its reliability has improved significantly since 2023.
Lowry said DTE’s “five-year, $270 million plan to modernize the electric system that serves the city” helped it deliver “the best electric reliability Ann Arbor has experienced in nearly 30 years” in 2025.
For the time being, A2SEU enrollment is optional for Ann Arbor residents and its generating resources supplement rather than replace DTE’s assets. But a citizen group calling itself Ann Arbor for Public Power is gathering signatures for a November ballot initiative that could start the years-long process of creating a full-fledged public utility in the city. DTE has spent nearly $2 million opposing the effort, according to financial disclosures reviewed by MLive.
Lowry said “municipalization” in Ann Arbor would cost residents and taxpayers $1 billion upfront and increase energy bills in the city by a “minimum” of 30% to 40%, per a DTE-commissioned report released in early 2025.
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The reliability watchdog is concerned about a series of “widespread and unexpected” customer-initiated load reductions in 2024 and 2025 during which 1,000 MW or more dropped off the bulk power system.
NextEra Energy Resources signed contracts for 1.3 GW of battery storage in the first quarter and expects to build 43 GW of battery storage by the end of 2032.
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“The dollar-per-kilowatt growth is going to be very healthy in the second quarter of this year,” CEO Scott Strazik said of turbine sales. The company also saw big jumps in orders for grid and wind power equipment.
In the first part of a two-phase plan, the grid operator would help match buyers, including data centers and other large loads, with sellers of new generation. States and utilities may seek to lower the procurement target over affordability concerns.
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Ty Pawb is already seeing strong returns from its recently installed solar PV system, with almost 42% of its electricity coming from solar power between January and March this year.
The 108 kWp system generated 38,730 kWh of clean electricity in just three months – helping save around £8,000 on energy bills.
During the same period, Ty Pawb used 92,450 kWh of electricity in total. Of that, nearly half was generated on-site, while the remaining 54,930 kWh was imported from the grid. A small surplus of 1,207 kWh was also exported back to the network.
Councillor Hugh Jones, Lead Member with responsibility for Ty Pawb said “Seeing such strong results so soon after installation is really encouraging. Ty Pawb is already cutting its energy bills and generating a significant proportion of its electricity on-site, which is good news both financially and environmentally.”
Strong early performance – even in winter
These results are particularly impressive given that January to March is typically one of the lowest sunlight periods of the year in the UK. Even so, the system has already delivered significant savings and a substantial level of on-site generation.
As daylight hours increase through spring and summer, generation is expected to rise further – increasing both financial savings and carbon reductions.
Better than expected
Although the system has only recently been installed, it’s already performing better than expected, meaning it’s likely to pay for itself sooner than originally planned.
At a time when energy costs continue to place pressure on public buildings, this early performance demonstrates the value of investing in renewable energy
Practical benefits of solar
Ty Pawb’s results highlight the practical benefits of solar PV, including:
Solar panels generate electricity from daylight throughout the year, even on cloudy days, making them a reliable and low-maintenance source of energy.
A practical example
This is a strong example of how a well-sized solar installation can make an immediate difference. By generating its own clean electricity, Ty Pawb is reducing costs now while supporting a more sustainable future.
 Councillor David A Bithell, Lead Member for Climate Change said “This project shows how investment in renewable energy can deliver practical benefits for public buildings. Not only is Ty Pawb reducing it’s reliance on the grid, but it’s also helping us move towards a more sustainable future.”
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Prepare For Summer With August Roofing & Solar: Santa Clarita’s Trusted Roofing & Solar Experts  KHTS Radio
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A scenario analysis by SolarPower Europe, modeled by Rystad Energy, finds that accelerating PV and battery storage deployment could save the European Union €223 billion ($260.7 billion) in gas imports between 2026 and 2030 and reduce wholesale electricity prices by 14% compared with 2025 levels.
Image: Michael Förtsch, Unsplash
The European Union is on track to miss both its 2030 solar and wind capacity targets under current deployment conditions. Under the modeled base-case outcome, solar is modeled at 574 GW against a target of 600 GW, while wind is modeled at 344 GW against a target of 425 GW – a shortfall of 19%, according to a new report from SolarPower Europe.
The analysis compares a business-as-usual base case with a higher-ambition “Solar+” scenario in which solar and battery storage deployment accelerates. In the Solar+ scenario, the European Union reaches 732 GW of solar capacity and 600 GWh of battery storage energy capacity by 2030 – nearly an eightfold increase compared with 77 GWh in 2025. The Solar+ scenario reaches a renewable electricity share of 68%, compared with the European Commission’s 69% indicative benchmark.
Under the Solar+ scenario, EU power system operating costs fall by 49% compared with 2025 levels, saving €55 billion annually. Wholesale day-ahead electricity prices drop by 14% on average across selected EU markets to €63.4/MWh. Among the markets assessed, Germany and Poland see the largest day-ahead price declines, of 25% and 16% respectively. Price volatility – measured by four-hour price spreads – falls by 42% across selected markets.
The report addresses the concern that higher solar penetration will undermine project economics through price cannibalization. It finds that pairing solar with battery storage raises PV plus battery energy storage system (BESS) capture prices by 73% on average across selected markets compared with standalone PV capture prices in 2025, with capture rates reaching 84%.
On energy security, the report calculates that PV avoided €27.4 billion in EU gas import costs in 2025. Under the Solar+ scenario, annual savings reach €53.3 billion by 2030, with cumulative savings of €223 billion between 2026 and 2030. The report notes that solar alone had saved the EU €8.5 billion in gas import costs since the start of the Middle East conflict, at the time of publication.
SolarPower Europe calls for an EU Flexibility Strategy with a dedicated Battery Storage Action Plan aligned with the EU’s existing 200 GW storage target for 2030, and a coordinated EU Electrification Action Plan. The report identifies structural and regulatory barriers, not technological ones, as the primary obstacles to deployment.
The Solar+ report was written by Raffaele Rossi and colleagues at SolarPower Europe, with modeling by Marius Mordal Bakke, Håkon Sletsjøe, and Fabian Rønningen at Rystad Energy.
The Solar+ findings extend a line of analysis SolarPower Europe has developed as EU solar deployment has accelerated but grid and market constraints have intensified. The European Union installed 65.1 GW of solar in 2025, but grid constraints now put more than 120 GW of renewable capacity at risk across the bloc, underscoring the structural barriers the latest report identifies. European solar manufacturing also remains considerably behind its own industrial targets, adding a supply-chain dimension to the deployment challenge.
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“It’s a benefit for the entire community.”
Photo Credit: iStock
Many people recognize rooftop solar as one of the most effective ways to lower electricity bills while reducing reliance on fossil fuels at home. Now, the benefits are reaching beyond homeowners. 
In Wayne County, West Virginia, 15 schools are installing solar systems to help fund teachers’ salaries, highlighting how businesses, public buildings, and local governments are also turning to clean energy to capture long-term savings.
According to Electrek, six rooftop systems were already finished as of February, with nine more on the way. Overall, the panels are expected to reduce energy costs by up to $200,000 per year once all projects are finished. 
For homeowners and public buildings alike, electricity costs can make up a significant share of annual bills. For Wayne County schools, the money saved on energy can be funneled back into classrooms.
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.
The school district locked in a fixed electricity rate through a long-term power purchase agreement with a local solar company. The deal also means the schools did not have to pay construction costs up front. 
If you’re curious about how much a solar panel system can reduce your energy costs, you can check out the free tools from EnergySage to get quick solar installation estimates and compare quotes. 
Wayne County Schools’ Todd Alexander said the solar projects should bring major savings over the lifetime of the panels. 
“In some of the projections we were looking at over the life of this PPA, it’s basically going to fund two teaching careers,” the superintendent said in a press release. “It’s a benefit for the entire community.”
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Want to go solar but not sure who to trust? EnergySage has your back with free and transparent quotes from fully vetted providers that can help you save as much as $10k on installation.
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 local options for your needs, and their expert advisers can help you compare quotes and pick a winner.
According to the release, the clean energy upgrade is expected to avoid about 2,400 metric tons of carbon dioxide emissions each year, roughly equivalent to the annual emissions from 560 gas-powered cars.
Those commenting on the Electrek article were quick to share their support for the Wayne County project.
“Another big win-win … schools pay lower energy costs, and surplus is sent out to the grid. Schools have a ton of rooftop real estate to install panels, so why not?” one wrote. 
“Do this everywhere!” another said. 
💡Go deep on the latest news and trends shaping the residential solar landscape
“Add some batteries and those schools become resilient community centers in an outage or emergency,” another added. 
Homeowners looking into how solar can transform their energy systems and savings can explore free resources from EnergySage. Those who consult with EnergySage experts can save up to $10,000 on installation costs. 
EnergySage even has a helpful mapping tool that shows the average costs of solar, state-by-state, with details on incentives. It can help consumers find the best price possible for panels in their region. 
To further boost savings or cut ties with the grid entirely, it may be worth pairing your solar panels with a battery backup system. EnergySage can help you there, too, with free resources on home energy storage. 
Get TCD’s free newsletters for easy tips, smart advice, and a chance to earn $5,000 toward home upgrades. To see more stories like this one, change your Google preferences here.
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A fire broke out on Tuesday afternoon at the Reserve Bank of India (RBI) building on Parliament Street in New Delhi after flames were detected in a solar panel installation on the rooftop. According to the Delhi Fire Service, the emergency call was received at around 1:05 pm, following which five to six fire tenders were rushed to the site.
The blaze was quickly brought under control within 15-20 minutes, preventing major damage or escalation. No injuries or casualties have been reported. Officials are currently investigating the exact cause of the fire, with preliminary reports indicating that the incident may have originated in a solar MCB or panel box system installed on the terrace.
A fire broke out at the Reserve Bank of India (RBI) building on Parliament Street in central Delhi on Tuesday, triggering a swift response from emergency services due to the building’s high-security status and critical financial function. Officials from the Delhi Fire Service confirmed that they received the first alert at approximately 1:05 pm, reporting smoke and flames emerging from the rooftop solar installation.
Within minutes, five to six fire tenders were dispatched to the location, and firefighting operations were initiated. According to early reports from fire officials and media briefings, the blaze was successfully contained within 15 to 20 minutes, preventing it from spreading to other parts of the building.
Preliminary assessments suggest that the fire originated in the solar panel system or its connected electrical components, including an MCB (Miniature Circuit Breaker) box installed on the terrace.
While the exact trigger is yet to be confirmed, officials have indicated that an electrical fault or overheating in the system is among the possible causes being examined. Importantly, no injuries or casualties have been reported, and all staff members were reported safe at the time of the incident.
The RBI building, located in one of the most sensitive administrative zones of the capital, is surrounded by key government institutions and experiences strict security monitoring. Given its importance in India’s financial ecosystem, any emergency at the site draws immediate coordinated response from fire, police, and security agencies.
Officials noted that the fire was controlled rapidly due to the prompt arrival of firefighting teams and the relatively contained nature of the incident. The Delhi Fire Service confirmed that the situation was brought under control shortly after firefighting began, with operations concluding within a short span of time.
Authorities are now carrying out a detailed inspection of the rooftop solar installation and associated electrical systems to determine whether the incident resulted from technical failure, maintenance issues, or overheating of equipment. At the time of reporting, no official statement has been released by the RBI regarding operational disruption or structural impact, suggesting that the core functioning of the institution remains unaffected.
The incident has once again brought attention to the increasing deployment of rooftop solar systems across government buildings in India as part of the country’s renewable energy transition. Institutions like the RBI have adopted solar infrastructure to reduce carbon footprint and operational energy costs, aligning with broader national sustainability goals.
However, experts have long pointed out that while solar energy is environmentally beneficial, it requires rigorous safety monitoring, particularly in dense urban areas and critical infrastructure zones. Electrical faults in solar panels, inverter systems, or circuit breakers if not regularly inspected can pose fire risks, especially during peak load conditions or extreme heat.
Recent fire safety discussions in urban India have also highlighted the need for stricter maintenance protocols, certified installations, and periodic audits for renewable energy systems installed in institutional buildings. While such incidents remain relatively rare, they underline the importance of balancing sustainability goals with robust infrastructure safety standards.
This incident at the RBI building is a reminder that India’s transition towards clean and renewable energy must be matched with equally strong attention to safety, regulation, and accountability. Solar power is a vital pillar of a sustainable future, but its implementation in sensitive and high-density environments demands uncompromising technical oversight and regular inspection.
Rather than viewing such incidents as setbacks to green energy adoption, they should be seen as opportunities to strengthen systems, improve maintenance protocols, and ensure that innovation does not outpace safety preparedness. Public institutions, in particular, must set benchmarks for safe and responsible integration of renewable technologies.
Also read: Pune FIR: Maharashtra Minister’s OSD Accused of Bat Attack, Strangulation Attempt, Son Injured
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