The University of New South Wales (UNSW) Sydney is addressing the challenge of managing end-of-life solar panels, via opening up an Australian-first research hub dedicated to recycling. UNSW Deputy Vice-Chancellor Research and Enterprise professor Bronwyn Fox says photovoltaic (PV) waste in Australia is forecast to reach 100,000 tonnes per year by 2030. “As we accelerate toward a net zero future, we must ensure the technologies enabling that transition are themselves sustainable,” Fox says. Funded by a $5 million grant from the Australian Research Council’s (ARC) Industrial Transformation Research Program, the hub will tackle pressing challenges through research and deep collaboration with industry. Hub Director professor Yansong Shen says there is an urgent need for a strong solar panel recycling industry, as many of Australia’s 3.5 million solar installations would reach end-of-life in the next decade. “End-of-life solar panels contain many valuable materials like glass, silicon, silver, and copper,” Shen says. “Our goal is to move these panels away from landfill and towards recycling in a circular economy where materials are recovered and reused.” Initiatives already underway at the hub include finding better ways to recover valuable materials from old solar panels, developing improved technologies to separate and sort panel components more efficiently, and redesigning panels so they are easier to be recycled. The hub will also advance policy by creating a network of researchers who will improve the entire value chain of solar panel production. Fox adds that the hub brings together Australian engineers, scientists, policy makers, and industry to transform end-of-life solar panels from an emerging waste challenge into a valuable resource. As previously reported, the World Economic Forum reports that there are several ways to increase recycling rates, including from solar panels. Solar panel recycling can recover up to 99% of material from decommissioned panels, preventing hazardous landfill waste and supporting a circular economy. Solar panels are considered important due to providing renewable and clean energy that reduces electricity bills and carbon footprint. According to the International Energy Agency (IEA), solar PV’s power capacity is poised to surpass that of coal by 2027. Solar PV generation increased by a record 320 terawatts per hour in 2023, reaching more than 1,600 terawatts per hour. The IEA says it demonstrated the largest absolute generation growth of all renewable technologies in 2023. Write toAaliyah Rogan at Mining.com.au Recent Stories
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UK-based consultancy Ricardo, part of the WSP Group, explains how solar PV has compounded at 17% annually since 2016, defining the EU’s clean-energy trajectory. However, straightforward merchant returns are disappearing, and battery storage and grid expertise are now essential. Image: Ihzuniga/Pixabay IRENA’s Renewable Capacity Statistics 2026, published on 2 April, records EU-27 installed renewable capacity at 779 GW as of end 2025, double the 387 GW a decade ago. The fleet has compounded at 8% per year. Solar PV has been the driving force. From 91 GW in 2016 to 367 GW by end 2025, the EU’s solar fleet has grown at a 17% compound annual rate, adding an average of 57 GW per year over the past three years. In 2025, solar accounted for 80% of all new EU-27 renewable capacity additions: 56 GW out of 70 GW total. Wind contributed 12 GW. Solar PV now makes up 47% of the entire EU renewable fleet. The top four markets (Germany, Spain, France, and Italy) account for 60% of the installed base. But the build-out is broadening. Poland’s 3.7 GW of solar in 2025 marks a significant shift for a coal-dependent economy. Bulgaria added 1.4 GW, expanding its entire prior fleet by 17% in a single year. Solar delivers where wind and hydro falter In 2025, EU renewable output grew by just 21 TWh despite capacity expanding 10%. Wind generation fell 11 TWh as fleet-wide capacity factors dropped from 24.6% in 2024 to 22.8% in 2025. Hydro lost 43 TWh from below-average rainfall across Southern and Central Europe. Solar was the sole technology that delivered more electricity year-on-year: 69 TWh more, a 24.6% increase, nearly offsetting the combined 54 TWh decline from wind and hydro. (Data based on Eurostat) At scale, solar is the most predictable large renewable technology on the grid. EU-wide solar capacity factors have held within a tight band of 11.4% to 12.0% for three consecutive years. Wind is far more variable: at 244 GW of installed capacity, a single percentage-point swing in EU wind capacity factors moves generation by 21 TWh. Batteries, grid, and the merchant revenue problem Midday price cannibalization is structural. In Spain, Germany, and increasingly Italy and Greece, wholesale day-ahead prices regularly fall to zero or below during peak solar hours in summer months. Each of these key markets recorded over 500 hours of negative prices in 2025. The result is that straightforward merchant returns from solar are disappearing. Corporate offtakers holding virtual PPAs are experiencing the same revenue erosion, as capture prices fall in step with market saturation. The assumption that grid expansion alone can solve solar oversupply does not hold under scrutiny. Figure 1 shows Germany’s cross-border electricity flows on Sunday 5 April 2026, a day when renewables exceeded domestic demand. German net exports ran at 8 to 9 GW overnight but collapsed to near zero during the midday solar peak. Poland and Czech Republic, which had been absorbing German surplus through the night, reversed direction and began pushing power back into Germany. The cables were not congested. Transmission capacity was available. The problem was that every neighboring market was also in surplus at the same time. When solar peaks simultaneously across central Europe, there is no price gradient to move power against. Interconnection enables cross-border trade, and Europe needs more of it for balancing variability and maintaining security of supply. But additional cables cannot solve a situation where every connected market is oversupplied during the same hours. The challenge has shifted from building renewable capacity to integrating what is already being built. This means managing the merchant, storage, and grid risks that accompany deep solar penetration, and making informed investment decisions in a market where the fundamentals have changed. Every EU member state has its own grid code, storage licensing regime, and ancillary services market design, navigating these differences, understanding where storage is profitable, where grid bottlenecks are binding, and where regulatory frameworks are evolving, is where substantive value now lies. Quantifying the risks: how can Ricardo`s Electricity Market Outlook help? Revenue modelling without credible curtailment and cannibalization projections is not fit for purpose. These are not tail risks to be footnoted in a sensitivity analysis. They are primary determinants of project returns. Ricardo’s Electricity Market Outlook is based on the proprietary PRIMES-IEM model, which runs all European markets simultaneously to deliver hourly prices out to 2050. Cross-border flows are derived by replicating the EUPHEMIA algorithm used by ENTSO-E. Built on a framework behind 20 years of European Commission policy analysis, the Electricity Market Outlook provides capture rate, negative price, and BESS profitability projections at country and asset level across EU markets. For investors, developers, and offtakers navigating a market where both battery economics and grid constraints shape project viability, the Electricity Market Outlook supports curtailment analysis, storage investment cases, and regulatory engagement with the quantitative foundation that bankability assessments require. Author: Safa Sen, Market Engagement Lead For CWE at Ricardo, Member of WSP. Ricardo is a member of professional service firm WSP Group, uniting engineering, advisory and science-based expertise to shape communities to advance humanity. From local beginnings to a globe-spanning presence today, it operates in over 50 countries and provides solutions and delivers innovative projects across sectors: Transport & Infrastructure, Property & Buildings, Earth & Environment, Water, Power & Energy and Mining & Metals. The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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The Australian Energy Market Commission (AEMC) has released a draft rule to modernise distribution network planning in response to the rapid uptake of consumer energy resources (CERs). The draft rule proposes introducing a new long-term planning framework and data reporting requirements to improve grid visibility and reduce consumer costs. Get Premium Subscription Published on 23 April, the draft determination responds to a rule change request submitted by Energy Consumers Australia in January 2025. It proposes replacing the existing distribution annual planning report with a distribution network development plan, published every five years with a standardised 20-year planning horizon. It would also establish a new framework for distribution network data reporting, with particular emphasis on improving visibility of the low-voltage network where most CERs connect. AEMC chair Anna Collyer said the reform will give decision-makers across the energy system better information to act earlier. “With detailed visibility of where solar, battery storage and electric vehicles (EVs) are emerging, distribution network service providers (DNSPs) and investors can plan ahead through targeted upgrades or non-network solutions,” Collyer said. “That means fewer constraints, less curtailment of rooftop solar, and ultimately more efficient investment decisions that flow onto everyone’s power bills.” The proposal comes as Australia’s distribution networks face mounting pressure from two-way energy flows. Rooftop solar capacity is forecast to reach 42.5GW by 2036, according to the Australian Energy Market Operator (AEMO), while battery storage and EV adoption continue to accelerate. These technologies are creating both opportunities for consumers and operational challenges for networks that were designed primarily for one-way power flows. Under the draft rule, distribution network service providers would be required to prepare a distribution network development plan in conjunction with their regulatory proposals, adopting inputs and scenarios consistent with AEMO’s Inputs, Assumptions and Scenarios Report where practicable. The framework allows DNSPs flexibility to deviate from AEMO’s scenarios to account for local factors and lower demand diversity at the distribution level. To maintain near-term transparency, DNSPs would also publish an annual update providing information on key changes to planning outcomes since the previous distribution network development plan. These updates would include summaries of completed or progressing regulatory investment tests for distribution projects, addressing concerns raised by stakeholders that a five-year planning cycle could reduce the frequency of public reporting compared to the current annual process. The draft rule establishes a principles-based framework for distribution network data reporting, requiring DNSPs to report data in accordance with guidelines prepared by the Australian Energy Regulator (AER). The AER would be required to develop these guidelines by 1 March 2028, with DNSPs required to comply within six months. The framework aims to address the current lack of consistent, granular data on the low-voltage network below zone substations, where congestion is becoming increasingly relevant as consumer energy resource volumes grow. Improved data availability would help consumers and investors understand existing network constraints, such as the potential for rooftop solar exports to be curtailed, before making investment decisions. Network costs make up close to half of a typical electricity bill, making efficient planning and investment decisions particularly important for consumers. The commission is seeking stakeholder feedback on the draft determination and rule, with submissions due by 4 June 2026. A final determination is expected in mid-2026.
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The province of Chubut announced the construction of a Photovoltaic Solar Park in Paso de Indios, which will mark the end of diesel-based electricity generation in the locality. The initiative, presented by Governor Ignacio “Nacho” Torres, involves a provincial investment of $8.4 billion and aims to significantly reduce fossil fuel consumption, greenhouse gas emissions, and generation costs. Torres highlighted that this project constitutes a historic advancement in strengthening the energy supply in the central plateau and will be the first step towards a profound transformation in the way energy is consumed in the province. The Photovoltaic Park will be integrated into a hybrid Smart Microgrid, which will replace the current diesel generator sets. Its main components include: The expected generation will reach 2.8 MWp, with real-time remote monitoring and combustion backup if needed. The annual demand of Paso de Indios (3,438 MWh) will be covered through: This will allow for a 20% reduction in fossil fuel dependence, increase the share of renewable energies, and improve the reliability of the electricity supply. Governor Torres emphasized that this project will be a pilot case that can be replicated in other municipalities and in the private sector, especially in energy-intensive industries. The construction will begin in June 2026 and is expected to be completed by February 2027, with the construction of a building that will function as the control center of the Photovoltaic Park. The Photovoltaic Solar Park of Paso de Indios represents a milestone in Chubut’s energy transition, by replacing an archaic and inefficient system with modern, sustainable, and long-term infrastructure. The initiative not only reduces costs and emissions but also strengthens energy security and paves the way for the province to become a national leader in renewable energies. Compartí esta nota
Independent power producer (IPP) Renalfa IPP has secured funding from the European Bank for Reconstruction and Development (EBRD) for its Szihalom 450MW solar-plus-storage project in Hungary. The EBRD’s investment will amount to €70 million (US$82 million) and is part of a €210 million financing package alongside commercial banks and marks the European financial institution’s first energy project financing in Hungary since 2010, said Anca Ionescu, EBRD’s regional head in Hungary, Slovakia and the Czech Republic. Get Premium Subscription Currently under construction, the Szihalom solar PV plant will be co-located with a 250MW/1GWh battery energy storage system (BESS) in north-eastern Hungary. According to EBRD, the financing of the utility-scale solar-plus-storage project represents a first of its kind for a hybrid renewable asset in Central and Eastern Europe. The project in itself is amongst the largest renewable energy development projects in Hungary. All the electricity generated by the solar PV plant will be directly sold in the Hungarian market without a support scheme or a corporate offtake agreement. “When operational later this year, this large hybrid asset will allow us to offer green baseload products to Hungarian electricity market and a number of flexibility services to the grid,” said Ivo Prokopiev, CEO of Renalfa IPP. Solar PV projects have been a significant contributor to reducing the contribution of coal to the Hungarian energy mix since 2019. According to thinktank Ember, solar contributed nearly one-quarter of the Hungarian energy mix in 2024. Renalfa IPP is a joint venture (JV) between Austrian investment company Renalfa Solarpro Group and French infrastructure fund manager RGreen Invest. Both companies recently partnered again to form another JV, called Renalfa Power Clusters, which will finance the construction of an €800 million pipeline of utility-scale hybrid assets co-located with BESS in Romania and Poland. Renalfa IPP owns and develops solar PV, wind and BESS projects across Central and Eastern Europe, with over 765MW of operating solar PV and wind assets and more than 510MW under construction. Its BESS portfolio currently sits at 622MW/2,300MWh of operational and under construction capacity.
China’s solar industry has launched its first TOPCon-focused patent pool, led by Trina Solar, JA Solar, and JinkoSolar, to streamline licensing, reduce disputes, and strengthen IP coordination at home and abroad. Image: Trina Solar China’s photovoltaic industry has formally launched its first patent pool, a move that could reshape how intellectual property is licensed and enforced across the country’s solar manufacturing value chain. The platform was unveiled in Beijing on April 21 at an event held under the guidance of the Ministry of Industry and Information Technology (MIIT) and the China National Intellectual Property Administration (CNIPA), with organizational support from the China Photovoltaic Industry Association (CPIA) intellectual property committee and the National PV Manufacturing Industry IP Operation Center. The patent pool was jointly initiated by Trina Solar, JA Solar, and JinkoSolar, and focuses on TOPCon solar cell and module patents in mainland China. According to disclosures at the launch event, the pool initially included 54 Chinese patents and patent applications. It is designed to operate on an open, market-based basis, combining cross-licensing among members with one-stop licensing for external implementers. Organizers said the model aims to improve licensing efficiency, reduce litigation, and mitigate the “patent thicket” risk as TOPCon technology matures. Reports from the event indicated that all rights holders are eligible to join, while licensing rates will be set with reference to market practice, national licensing data, and comparable agreements. A separate expert guidance committee comprising 14 specialists has been established to oversee compliance, legal robustness, and antitrust considerations. The new patent pool appears to represent an industry-level effort to shift competition away from pricing alone and toward technology value, licensing discipline, and coordinated overseas enforcement. A Chinese media report published on MIIT’s official website linked the initiative to broader efforts to curb “involution-style” competition and strengthen IP protection in strategic emerging industries. For exporters, the pool may also provide a more coordinated framework for addressing overseas patent challenges as Chinese PV companies expand in Europe and other key markets. The launch follows a period of increasingly visible patent disputes within China’s solar sector, particularly around TOPCon. In September 2025, Longi and JinkoSolar announced a global settlement covering ongoing patent claims and disputes between the parties and their affiliates, ending litigation and establishing cross-licensing arrangements for certain core patents. A similar case followed in November 2025, when JA Solar and Astronergy reached a global settlement covering ongoing patent disputes, agreed to terminate related legal proceedings, and entered into cross-licensing for their TOPCon portfolios.
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A group of Microsoft suppliers just helped push a small solar farm over the finish line in North Carolina – and it shows how corporate buyers can band together and boost projects that might otherwise stall. Clean energy marketplace Ever.green says a 5-megawatt (MW) solar project called Baron is now online in Anson County, 45 miles southeast of Charlotte. Headwater Energy will develop, own, and operate the project. Here’s what’s notable about Baron: Instead of one big corporate buyer stepping in, a group of Microsoft suppliers signed long-term contracts for renewable energy certificates (RECs) tied to the solar farm. That group includes Slalom Consulting, Centific Technologies, ImagiCorps, BDA, Eleven 11 Solutions, TASA Analytics, and Visionet Systems. Those commitments helped the project reach financial close – a key hurdle that often trips up smaller solar developments. Microsoft has been pushing its supply chain to clean up its energy use. Under its Supplier Code of Conduct, certain large-scale suppliers are expected to move to 100% carbon-free electricity (CFE) for the goods and services they provide to Microsoft by 2030. That pressure is starting to show up in deals like this one. Small and mid-sized solar projects often get stuck before construction because lenders want to see guaranteed revenue. Even if a project makes sense on paper, it can stall if buyers aren’t locked in. In Baron’s case, the participating suppliers collectively committed to enough RECs to give lenders the confidence to move forward. Ever.green is trying to make that model easier to replicate. Instead of buying RECs from existing projects on the spot market, its “high-impact” RECs are tied to new builds, so the purchase actually helps bring new clean energy online.
“Ever.green was designed specifically to make this kind of collective action possible. We’re one of the few organizations that empowers companies of all sizes to advance their carbon-free electricity goals by acquiring High-Impact RECs that have real impact at the community level,” said Liz Pearce, chief revenue officer at Ever.green. The Baron solar farm is now generating electricity for the local grid that serves Pee Dee Electric, part of the regional cooperative system. While one project won’t set electricity rates, adding solar can help reduce exposure to volatile fuel prices over time. The project is also expected to make a positive local impact. It’s located in a rural, low-income county and will generate property tax revenue that supports schools, emergency services, and other public services. Built with domestically manufactured panels and local labor, Baron Solar is expected to avoid about 7,810 metric tons of CO2 emissions each year — roughly the same as taking around 1,820 cars off the road annually. For the companies involved, it’s also about meeting their own climate targets. Slalom, for example, says it’s aiming for 100% renewable energy by 2030, and projects like this are part of that effort. Deals like this are still relatively small in scale, but they point to a growing trend: companies banding together to finance clean energy projects that might not come to fruition on their own. Read more:Qcells to supply Microsoft with a whopping 12 GW of solar panels If you’re looking to replace your old HVAC equipment, it’s always a good idea to get quotes from a few installers. To make sure you’re finding a trusted, reliable HVAC installer near you that offers competitive pricing on heat pumps, check out EnergySage. EnergySage is a free service that makes it easy for you to get a heat pump. They have pre-vetted heat pump installers competing for your business, ensuring you get high quality solutions. Plus, it’s free to use! Your personalized heat pump quotes are easy to compare online and you’ll get access to unbiased Energy Advisors to help you every step of the way. Get started here. – *ad FTC: We use income earning auto affiliate links.More. Subscribe to Electrek on YouTube for exclusive videos and subscribe to the podcast. Electrek Green Energy Brief: A daily technical, … Michelle Lewis is a writer and editor on Electrek and an editor on DroneDJ, 9to5Mac, and 9to5Google. She lives in White River Junction, Vermont. She has previously worked for Fast Company, the Guardian, News Deeply, Time, and others. Message Michelle on Twitter or at michelle@9to5mac.com. Check out her personal blog. Light, durable, quick: I’ll never go back. Because I don’t want to wait for the best of British TV.
Please log in, or sign up for a new account and purchase a subscription to continue reading. Please log in, or sign up for a new account and purchase a subscription to continue reading. Join now to continue reading. Your current subscription does not provide access to this content. Don’t hesitate! Start your digital-only membership today and not only receive full access to our premier news website NNY360.com but also to the NNY360 mobile app, and the Watertown Daily Times eEdition! Sorry, no promotional deals were found matching that code. Promotional Rates were found for your code. Sorry, an error occurred.
do not remove Rain showers this evening with overcast skies overnight. Low around 35F. Winds NNE at 5 to 10 mph. Chance of rain 60%.. Rain showers this evening with overcast skies overnight. Low around 35F. Winds NNE at 5 to 10 mph. Chance of rain 60%. Updated: April 23, 2026 @ 8:40 pm The Sugar Maple Solar project in Jefferson and Lewis counties has been approved by the state. Watertown Daily Times
The map shown, included in the public involvement program plan, indicates the project area for the Sugar Maple Solar farm. Provided image
The Sugar Maple Solar project in Jefferson and Lewis counties has been approved by the state. Watertown Daily Times
The map shown, included in the public involvement program plan, indicates the project area for the Sugar Maple Solar farm. Provided image
ALBANY — The state Department of Public Service has given the final approval for developers to move forward with a 622-acre solar farm in the towns of Wilna and Croghan, expected to be one of the larger solar facilities in the state once completed. On Wednesday, the DPS stamped its final approval on the permit for Sugar Maple Solar to move forward with its project, which once completed is expected to produce up to 125 megawatts of power, enough for more than 30,000 homes. The approval doesn’t ensure that work will go forward; the developer still needs to hammer out agreements with the towns, including potential Payment in Lieu of Taxes (PILOT) agreements, before they can break ground. According to the details of the permit, the project will include a 20-megawatt battery energy storage system capable of providing power to the grid for up to four hours once charged. According to the permit, the developers requested that the state allow them to ignore certain aspects of Croghan and Wilna’s zoning laws; the DPS permit broadly blocks the developers from ignoring most of the town’s zoning rules, although it did rule that the project doesn’t have to follow the town of Croghan’s solar facility overlay zone rules, its state road setback rules, its forest clearing restrictions and a handful of other town-level regulations, as well as the town of Wilna’s decommissioning bonds requirement and decommissioning plan requirements. {{description}} Email notifications are only sent once a day, and only if there are new matching items. Your comment has been submitted.
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It was Earth Day yesterday, and organizations across the region are taking advantage of the holiday to flip the switch on power-producing solar arrays this week. Ozarks at Large’s Jack Travis attended a ribbon-cutting ceremony for the University of Arkansas’ project and brings us this report. The University of Arkansas flipped the switch on its system-wide solar energy project yesterday. The first of four solar arrays deploying across the state came online, and this one benefits the Fayetteville campus. Although the group of panels on Wedington Drive is the smallest of the four, they still have a huge impact on one part of the university. “This facility here is offsetting 100% of the electricity consumed at the Cato Springs Research Center.” Eric Boles is the director of sustainability for the university. He oversees off-site energy production and says he spends a lot of time convening stakeholders, talking about how to reduce their environmental footprint through the electricity that facilities consume. “That was kind of our role within this project. The UA Fayetteville campus had the first solar projects within the U of A system, and that planted the seed that grew into a system-wide project, which is hugely beneficial to all the campuses within the University of Arkansas system and for the state of Arkansas.” The seed was planted in 2019 and resulted in a new solar services agreement in 2022. In that agreement, the Board of Trustees pledged to cut greenhouse gas emissions by 8.8% and pursue a solar array to cover roughly 6.3% of the Fayetteville campus’s energy requirement. Senior advisor and project manager for utility operations, Scott Turley, says that growing the agreement to cover the statewide university system allowed for easier approval. “We were successful in getting one project approved by the board, and that was when they started thinking, should we look at this as a system-wide project as opposed to a campus by campus?” Now, the solar project has grown to over 20 planned facilities stationed across Arkansas. Yesterday, the first came online in Fayetteville, but later this year, three more will activate around Paris, Nashville and Murfreesboro. The first phase will generate about 993,000 kilowatt-hours of energy a year. That’s enough to power 125 homes, possibly saving the university over $100 million over the next 25 years. This initiative will put the U of A on the map for sustainable energy, as it’s the fourth largest university solar deployment in the U.S. Only Stanford, the University of California System and Penn State have larger installations. However, officials at yesterday’s ribbon-cutting ceremony say that ours is more complicated. The power plant works under old net metering laws. These laws allow the university to exchange electricity on the grid, so the Cato Springs Research Center is currently benefiting from the solar panels, even though they’re across town. These net metering laws in Arkansas changed a couple of years ago, but Boles says it would be difficult to use the new system without them. “We’re 15, 20 minutes away by car. Kind of how it works is through the net metering laws in the state of Arkansas, we are grandfathered in under the previous net metering laws, which allow us to — for every unit of electricity we put into the grid here, we get one unit of electricity out of the grid at our Cato Springs Research Center. A lot of times these projects make sense to do as a net metering system because you’re able to really deploy solar at scale. This whole project is hundreds of acres. It’s more land than we have on the campus. And in addition, sometimes it makes sense to build the facilities where the land is available. You have a lower cost to deploy the facility and you have a demand for electricity at that location.” Turley, amidst the panels and the audible whine of solar power generation, says the new solar project is great for the university’s many priorities and stakeholders. For starters, it’s just good business sense. “It saves the university money and that frees up resources for our core mission. At the same time, we can have a dramatic impact on our sustainability goals and the reduction in our carbon emissions. It’s also a good marketing tool. Students want to be a part of a campus that is progressive and being environmentally responsible. So it’s really a win for the university all the way around.” Ozarks at Large transcripts are created on a rush deadline and edited for length and clarity. Copy editors utilize AI tools to review work. KUAF does not publish content created by AI. Please reach out to kuafinfo@uark.edu to report an issue. The audio version is the authoritative record of KUAF programming.
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Windows that generate energy: What is photovoltaic glass? Essentially, photovoltaic glass incorporates materials capable of transforming solar radiation into electricity within the glass itself. Unlike traditional solar panels, these solutions can be transparent or semi-transparent, allowing natural light to pass through while producing energy, as reported in Applied Energy 2025.
The principle is the same as that of any other photovoltaic technology: certain semiconductor materials absorb solar radiation and generate electric current. In this case, the difference lies in the selection of the light spectrum.
The most advanced solutions mainly capture non-visible radiation (such as ultraviolet or infrared) to maintain the transparency of the glass. Technologies such as organic cells, perovskite, and luminescent concentrators are behind these advances.
In this context, the evolution of new materials is key. In fact, innovations such as perovskite solar cells, capable of exceeding 27% efficiency in the laboratory and with potential for flexible or surface-integrated applications, are opening new pathways to developingsolar energy beyond conventional panels.
Architectural integration: great potential in buildings
This technology shows the greatest potential in architectural integration. According to the National Renewable Energy Laboratory (NREL), glazed surfaces (windows, facades, or skylights) represent a significant part of building exteriors.
In commercial buildings, the high proportion of glazed surfaces represent a great opportunity to generate energy without the need to occupy additional space on roofs. In addition to generating electricity, these systems can also improve the energy performance of the building, contributing to interior thermal comfort and reducing the demand for air conditioning, thus optimizing efficiency.
For all these reasons, technology in this context, such as photovoltaic solutions that are integrated into buildings, is positioned as a key tool to reduce emissions and advance urban decarbonization.
What challenges does it present for future development?
Despite their potential, photovoltaic glass still faces important challenges that reflects the complexity of its industrial development, such as the rigorous certification processes and reliability tests it must go through.
Moreover, there is a key limitation: the balance between transparency and efficiency. While conventional solar panels usually exceed 20% efficiency, transparent photovoltaic solutions present somewhat lower yields due to the balance between transparency and energy generation. Therefore, it could be said that this balance between performance and transparency is one of the main technological challenges currently faced by this energy solution.
One more piece of sustainable urban planning
Despite these challenges, it is worth noting that progress is continuous and is part of a broader transformation of the energy model. In fact, according to the International Renewable Energy Agency (IRENA), renewable energy accounted for 92.5% of the new global installed electricity capacity in 2024.
In parallel, the development of solutions such as building-integrated photovoltaics responds to a growing trend towards more efficient, electrified, and decarbonized cities. In this regard, the European Commission establishes that new buildings must move towards nearly zero-energy building (NZEB) models, which implies, among other aspects, integrating renewable energy generation into the building itself, including its exterior elements, such as facades, roofs, or glazed surfaces.
As with other solar innovations, the challenge is not only to capture more energy, but to better integrate it into the spaces where we live and work. Because the future of energy isn’t just about producing more, but about doing so in a smarter, more efficient way that is integrated into our surroundings.
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The Australian Energy Market Commission (AEMC) has released draft technical standards requiring large data centres to remain connected during grid faults, following international incidents in which facilities simultaneously disconnected during disturbances, causing cascading blackouts. AEMC’s proposed standards arrive as social backlash appears inevitable unless the industry stops freeloading on Australia’s clean energy, with a coalition of climate groups, unions and renewable energy organisations demanding that new facilities provide their own firm renewable energy sources or face community opposition. Get Premium Subscription Data centres currently consume approximately 3.9TWh of energy annually, representing 2% of Australia’s total electricity consumption. However, Oxford Economics projections developed for AEMO indicate this could surge to 32TWh by 2050 – equivalent to 12% of national consumption and potentially adding another manufacturing sector’s worth of demand to the grid. The technical challenge is significant. Most data centres use inverter-based technology similar to wind and solar PV power plants, which can suddenly disconnect during grid disturbances. When multiple facilities disconnect simultaneously, the results can be catastrophic. For instance, in July 2024, 60 data centres in Virginia pulled 1,500MW off the grid during a single fault, causing cascading failures and grid instability. Similar incidents in Ireland and Texas have prompted some jurisdictions to halt new data centre connections entirely. “Data centres aren’t passive loads anymore; they’re active grid participants,” said AEMC Chair Anna Collyer. “When they fail to ride through faults, it has the potential to trigger cascading failures and blackouts. We have seen this happen overseas, and it can cost consumers billions in lost electricity supply or emergency network upgrades.” The AEMC’s draft rule establishes a clear three-tier classification system for distribution-connected loads, moving away from the current 5MW threshold to a more nuanced approach that recognises actual grid impact. Under the proposed framework, Tier 1 connections would apply to inverter-based loads up to 30MW and all non-inverter loads regardless of size. Tier 2 covers inverter-based loads between 30-100MW, while Tier 3 applies to facilities 100MW or greater. The Schedule 5.3 access standards would apply at the network service provider’s discretion for Tier 1 and Tier 2 connections, but would apply automatically for all Tier 3 facilities. The new standards would require large data centres to meet specific disturbance ride-through requirements, staying connected during voltage and frequency disturbances and recovering power within defined timeframes. Crucially, the AEMC has aligned these standards with those used or proposed in Texas, Ireland and Finland, enabling data centre operators to use the same equipment and feasibility studies across jurisdictions. This standardised approach promises faster deployment, lower costs and better investment certainty – critical factors as AI and data centre demand is set to more than double by 2030. The International Energy Agency (IEA) projects global electricity demand from data centres will surge to 945TWh annually by 2030, with AI-optimised facilities quadrupling in the same period. The technical requirements address the fundamental difference between data centres and traditional industrial loads. While mines, refineries and processing plants typically comprise heterogeneous motors and resistive processes that follow prevailing grid conditions, data centres connect through actively controlled power electronic converters whose behaviour during disturbances is shaped by software and control systems. “Large inverter-based loads can rapidly reduce or cease demand during voltage and frequency disturbances, interact dynamically with system strength, contribute limited fault current, and affect stability in weaker grid conditions,” the AEMC noted in its draft determination. “In aggregate, this behaviour can influence disturbance outcomes and, if not appropriately managed, increase the risk of cascading events.” Major technology companies are already demonstrating how data centre expansion can align with clean energy development. Amazon’s AU$20 billion (US$14 billion) investment in Australian data centres powered by solar PV represents one of the largest commitments to renewable-powered digital infrastructure in Australia, while Microsoft has secured a 15-year power purchase agreement for a 353MW solar plant in New South Wales. These investments suggest the industry recognises that Australia can turn the data centre boom into a grid growth story rather than a burden on existing infrastructure. The AEMC’s proposed standards aim to support this transition by ensuring that new facilities contribute to, rather than detract from, grid stability. The draft rule also includes provisions for data centres to provide grid support services, recognising that properly managed facilities could become valuable grid assets. Requirements for demand response, storage deployment and participation in contingency services would help strengthen overall system resilience. Beyond the immediate technical standards, the AEMC’s proposal addresses broader regulatory clarity issues that have created uncertainty for both developers and network service providers. The current framework, originally designed for conventional generation and passive loads, has led to inconsistent application of technical requirements across different network operators. “Without a clear and fit-for-purpose framework to classify large inverter-based loads and determine how the technical access standards apply to each category, network service providers may interpret and apply those standards inconsistently,” the AEMC noted. “This uncertainty can lead to delays in the connection process and result in real cost impacts.” The AEMC is seeking stakeholder feedback on the draft rule by 7 May 2026, with a final rule expected mid-2026. To support implementation, AEMO will publish interim guidelines in the coming months to help network service providers and data centre developers prepare for the proposed changes. The Energy Storage Summit Australia 2026 will be returning to Sydney on 18-19 March. It features keynote speeches and panel discussions on topics such as the Capacity Investment Scheme, long-duration energy storage, and BESS revenue streams. ESN Premium subscribers receive an exclusive discount on ticket prices. To secure your tickets and learn more about the event, please visit the official website.
The U.S. Commerce Department has imposed preliminary antidumping duties on solar cells and panels from India, Indonesia, and Laos. These tariffs, ranging from 22.46% to 123.04%, are the latest in a series of measures targeting cheap solar imports from Asia over the past decade. (Catch all the Business News, Breaking News and Latest News Updates on The Economic Times.) Subscribe to The Economic Times Prime and read the ET ePaper online. (Catch all the Business News, Breaking News and Latest News Updates on The Economic Times.) Subscribe to The Economic Times Prime and read the ET ePaper online. Hot on Web In Case you missed it Top Searched Companies Top Calculators Top Prime Articles Top Slideshow Top Commodities Most Searched IFSC Codes Top Story Listing Private Companies Top Definitions Latest News Follow us on: Find this comment offensive? Choose your reason below and click on the Report button. This will alert our moderators to take action Reason for reporting: Your Reason has been Reported to the admin. Log In/Connect with: Will be displayed Will not be displayed Will be displayed 15 Days Free: Unlock All ETPrime Exclusives, Market Tools & ePapers Trial offer expiring in00 : 05 : 00 Worry not. You’re just a step away. It seems like you’re already an ETPrime member with Login using your ET Prime credentials to enjoy all member benefits Log out of your current logged-in account and log in again using your ET Prime credentials to enjoy all member benefits. Big Price Drop! Flat 40% Off
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DAEGU, South Korea, April 23, 2026 /PRNewswire/ — Amid growing demand in Korea for efficient, reliable, and advanced cell technologies, Tongwei Solar appeared at Green Energy Expo 2026. On April 23, the company held an on-site presentation on advanced cell technologies, highlighting its TNC series high-efficiency cells and the latest progress of the TNC 3.0 multi-cut cell in product performance, technology advancement, and value delivery.
Tongwei Solar Highlights Advanced Cell Technologies and TNC Product Value at Green Energy Expo 2026 in Korea
As a key focus of the exchange, Tongwei Solar introduced the product evolution of its TNC 3.0 multi-cut cell. Integrating TPE, multi-cut, and Poly Tech technologies, and moving relevant optimization steps forward to the cell side, the product further reduces loss and enhances performance to support downstream value delivery. Through this coordinated approach, the TNC 3.0 multi-cut cell delivers module power gain of 10W+, bifaciality boost of 5%, and conversion efficiency of over 26.3%, creating greater value for high-efficiency modules. Tongwei Solar, a core subsidiary of Tongwei Co., Ltd., focuses on the R&D and manufacturing of high-efficiency crystalline silicon solar cells. The company has over 150GW of cell production capacity, more than 400GW in cumulative shipments, and has ranked No. 1 globally in cell shipments for nine consecutive years, according to InfoLink Consulting. Backed by the Tongwei Global Innovation R&D Center, Tongwei continues to advance solar cell technology and drive PV innovation. In September 2025, Tongwei Solar's Meishan company was recognized as the world's first Lighthouse Factory in the photovoltaic cell industry. Supported by lighthouse-level intelligent manufacturing, cell-level traceability, and full-process quality control, Tongwei Solar continues to strengthen product stability and reliability while providing rapid response, technical exchange, and application support to overseas customers. With strengths in products, R&D, manufacturing, and quality, Tongwei Solar is bringing the Korean and global markets a more efficient, reliable, and long-term solar choice. For more information, please visit: https://en.tongwei.cn/
The U.S. Commerce Department has imposed preliminary tariffs on solar cells and modules from India, Indonesia, and Laos, with rates up to 143.30%. This move sharply increases import costs for U.S. renewable energy projects, adding to challenges from higher interest rates and changing federal incentives, which could slow solar deployment. Used by 10,000+ active investors Select the stocks you want to track in real time. Receive instant updates directly to WhatsApp. The U.S. Commerce Department has imposed preliminary countervailing duties (CVD) on solar imports from India, Indonesia, and Laos, marking a key moment for the renewable energy sector. These duties, aimed at countering alleged government subsidies, range from 125.87% for India to as high as 143.30% for some Indonesian exporters, with Laos facing an 80.67% preliminary rate. This action, initiated after investigations by domestic manufacturers, is expected to increase the cost of solar modules and cells entering the U.S., impacting the entire value chain and potentially hindering the nation's clean energy goals. The preliminary findings, announced on February 24, 2026, show a strong focus on trade enforcement in the solar industry. The Commerce Department found that producers in these three nations benefited from unfair government subsidies. As a result, U.S. Customs and Border Protection has started collecting cash deposits on these imports at the preliminary duty rates, immediately raising costs for affected shipments. This comes at a sensitive time for the U.S. solar market, which is already facing higher financing costs due to elevated interest rates. For U.S. solar developers and installers, these tariffs mean higher project expenses, a factor that could reduce the profitability of new installations and slow renewable energy adoption. The broader U.S. solar market installed about 43.2 GW in 2025, a 14% decrease from the previous year, indicating existing market pressures. These escalating duties are changing the global solar supply chain, with attention shifting to countries not directly targeted. While Thailand faced tariffs up to 3,500% and a 37% reciprocal tax, other Southeast Asian nations like Vietnam and Malaysia are significant solar manufacturing hubs. India, Indonesia, and Laos are now subject to specific, high CVD rates. Malaysia, for instance, remains a key exporter to the U.S., accounting for 22.9% of its PV exports in 2022. Vietnam is projected to see its solar panel market grow significantly, driven by industrial expansion and government initiatives. The U.S. government's prior Section 201 tariffs, implemented in 2018 and extended through 2026, had already increased import costs. Their overall impact on project economics was somewhat lessened by falling panel prices and the growing share of 'soft costs' like permitting. The current preliminary CVDs, however, represent targeted and potentially much higher increases. The U.S. solar industry has historically faced changing policy environments, including extensions and modifications of tariffs under different administrations. Moreover, economic conditions are tough; persistently high interest rates increase the cost of capital for solar projects, making them less competitive against fossil fuels and complicating financing. The recent phasing out of key federal tax incentives, such as the Investment Tax Credit (ITC), by 2025/2027, further pressures project economics. Analyst sentiment for the U.S. solar sector is cautiously optimistic due to rising energy demand and policy support, with some expecting significant long-term growth, but short-term cost pressures are clear. The Commerce Department's actions are presented as a way to protect domestic manufacturing. However, the very high preliminary duties, particularly for India and Indonesia, could severely harm the U.S. renewable energy transition. Companies like First Solar, a major U.S. manufacturer, already have substantial manufacturing capacity. While these tariffs aim to protect them, they also increase the cost of components for other U.S. players or create a situation where domestic production capacity cannot meet demand quickly enough, leading to project delays and higher consumer prices. Reliance on specific countries for manufacturing and assembly, even those not currently targeted by these CVDs, means that supply chain weaknesses remain. The history of tariffs shows that foreign producers often shift operations or reroute products to avoid duties, potentially leading to complex investigations and further trade disputes. Furthermore, the combination of these tariffs with already elevated interest rates and the rollback of federal tax credits could reduce investment. For instance, rising interest rates can increase the total cost of solar power (Levelized Cost of Electricity or LCOE) by up to a third. Whether these duties will truly revive U.S. manufacturing, instead of just increasing costs for American consumers and businesses, is a significant question. There is also the possibility of retaliatory actions from affected countries, further disrupting global trade. The U.S. solar industry is a complex ecosystem; artificially inflating component costs could harm smaller installers and project developers more than it helps large-scale domestic manufacturing in the short to medium term. The preliminary CVD decisions are still subject to finalization. Decisions on antidumping duties are also expected around April 2026, with final combined rates anticipated by early September 2026. The U.S. International Trade Commission will also make a final determination on whether imports cause injury later in the year. The full impact of these duties will depend on these final rulings, possible appeals, and how quickly supply chains adjust. While the U.S. solar market is projected for substantial growth through 2030 and beyond, driven by demand and evolving energy policies, these new tariff structures bring significant cost uncertainty and could slow the achievement of these targets by making solar projects more expensive to finance and build. Quarterly results, bulk deals, concall updates and major announcements delivered in real time. Used by 10,000+ active investors Select the stocks you want to track in real time. Receive instant updates directly to WhatsApp.
Renewables Now is a leading business news source for renewable energy professionals globally. Trust us for comprehensive coverage of major deals, projects and industry trends. We’ve done this since 2009. Stay on top of sector news with with Renewables Now. Get access to extra articles and insights with our subscription plans and set up your own focused newsletters and alerts.
Thank you for visiting nature.com. You are using a browser version with limited support for CSS. To obtain the best experience, we recommend you use a more up to date browser (or turn off compatibility mode in Internet Explorer). In the meantime, to ensure continued support, we are displaying the site without styles and JavaScript. Advertisement Scientific Reportsvolume 16, Article number: 12293 (2026) Cite this article 1475 Accesses Metrics details 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 1st, 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 1st, 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 1st, 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 1st, May 1st, July 1st, and October 1st, 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 1st, May 1st, July 1st, and October 1st, 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 1st, relative humidity peaked at 90% at 06:00 AM, gradually reducing to 42% by 19:52 PM. A similar trend was observed on January 1st, where humidity started at 67% at 06:00 AM and dropped to 45% by 19:48 PM. On May 1st and July 1st, 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 1st. 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 1st (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 1st 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 1st 2016, a spring day. PERRIN DE BRICHAMBAUT estimated inclined solar radiation compared with experimental data on July 1st 2016, a summer day. PERRIN DE BRICHAMBAUT estimated inclined solar radiation compared with experimental data on October 1st 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 1st, 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 1st, 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 1st, 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 1st. 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 1st. 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 1st and July 1st), while low wind speeds with high humidity occur in winter and fall (January 1st and October 1st). 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 findings52,53,54,55. 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 studies58,59,60 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). GT = Global inclined solar radiation [W/m2]. S = Direct radiation on an inclined plan [W/m2]. Dciel = Diffuse radiation on an inclined plan [W/m2]. Dsol = 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 1st (Winter), May 1st (Spring), July 1st (Summer), and October 1st (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 1st (a winter day) and October 1st (a fall day), particularly at sunrise, sunset, and midday. On January 1st, the experimental peak solar irradiance was 927.61 W/m2, with a predicted value of 865.45 W/m2 around midday. On October 1st, the maximum measured value was 1021.9 W/m2, while the estimated value was 980.94 W/m2. On May 1st (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 1st (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 literature52,53,54,55,56,57,58,59,60,61,62,63,64,65,66. 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 1st (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 1st, 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 1st. 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 1st, 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 1st, May 1st, July 1st, and October 1st, representing the four seasons. Comparison of output power (kW) between fixed and single-axis PV subfields for mc-Si and pc-Si on January 1st, 2016. A winter day . Comparison of output power (kW) between fixed and single-axis PV subfields for mc-Si and pc-Si on May 1st, 2016. A spring day . Comparison of output power (kW) between fixed and single-axis PV subfields for mc-Si and pc-Si on July 1st, 2016. A summer day . Comparison of output power (kW) between fixed and single-axis PV subfields for mc-Si and pc-Si on October 1st, 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 1st, 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 1st, 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 1st, 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 1st, 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 1st, 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 1st, May 1st, and July 1st. 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 1st, May 1st, July 1st, and October 1st 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 1st. The fixed mc-Si technology reached its peak panel surface temperature of 33.16 °C on July 1st and its lowest of 23.02 °C on May 1st, 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 1st. These distinct temperature changes vividly illustrate the seasonal performance variations of these PV technologies. On July 1st, 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 1st, 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 1st, 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 1st, a fall day. On January 1st, a winter day, the irradiance was 730.94 W/m2, while on May 1st, 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 1st. On May 1st, it recorded 576.68 W/m2. During winter (January 1st) and fall (October 1st), the irradiance values were 502.77 W/m2 and 449.67 W/m2, respectively. On May 1st, 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 1st, May 1st, and July 1st. 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 1st revealed that single-axis subfields benefited the most from increased solar irradiance, resulting in notable power gains74. On July 1st, 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 1st, 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 1st, conditions were particularly advantageous for both fixed and motorized panels, leading to higher energy yields. A similar trend was observed on May 1st, 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 1st and July 1st 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 1st and July 1st, 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 (%). Pbaseline: Mean output power (KW) of the baseline (reference) technology or subfield. Pnew : 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 1st, 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 1st, 2016 (winter day). In Fig. 19 the results of an experiment conducted on May 1st, 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 1st, 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 1st, 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 1st, 2016 (spring Day). On October 1st, 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 1st, 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 1st, 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 1st can be attributed to the weak solar radiation and the shorter duration of daylight typical of winter. The data recorded on May 1st 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 1st, 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 1st, 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 1st 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 1st ), 55.20 kW (fixed mc-Si, January 1st ), and 56.94 kW (single-axis pc-Si, May 1st ), with 48.76 kW for the same subfield on January 1st. 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 1st and 730 W/m2 on May 1st, 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 1st, 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 1st and May 1st. 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 1st for mc-Si (3.263%) and on October 1st for pc-Si (11.791%). The analysis confirmed the superior performance of single-axis tracking systems in energy production. On May 1st, 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 1st, and 636.15 kWh/day and 553.43 kWh/day on July 1st. 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. 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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 Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar Search author on:PubMedGoogle Scholar 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. Correspondence to Bouramdane Abderraouf or Daniel Limenew Meheretie. The authors declare no competing interests. Springer Nature remains neutral with regard to jurisdictional claims in published maps and institutional affiliations. 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To view a copy of this licence, visit http://creativecommons.org/licenses/by-nc-nd/4.0/. Reprints and permissions 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 Rep16, 12293 (2026). https://doi.org/10.1038/s41598-026-41570-8 Download citation Received: Accepted: Published: Version of record: DOI: https://doi.org/10.1038/s41598-026-41570-8 Anyone you share the following link with will be able to read this content: Sorry, a shareable link is not currently available for this article.
An official website of the United States government Here’s how you know Official websites use .gov A .gov website belongs to an official government organization in the United States. Secure .gov websites use HTTPS A lock ( ) or https:// means you’ve safely connected to the .gov website. Share sensitive information only on official, secure websites. Funding Opportunities The U.S. Department of Energy (DOE) Solar Energy Technologies Office (SETO) Fiscal Year 2022 Solar Manufacturing Incubator is a $24 million funding program designed to accelerate commercialization of innovative product ideas that can increase U.S. domestic manufacturing across the solar industry supply chain and expand private investment in America’s solar manufacturing sector, including the advancement of cadmium telluride (CdTe) photovoltaic (PV) technologies. DOE announced the funding opportunity on July 14, 2022 and announced the 9 selected projects on April 20, 2023. On May 18, 2023, DOE announced that an additional project was awarded $1.6 million. This funding program seeks to invest in innovative research, development, and demonstration projects that enable continued solar cost reductions, while developing next-generation solar technologies and boosting American solar manufacturing, especially in CdTe PV. These projects support the scaling of affordable solar and facilitate secure, reliable integration of solar electricity into the nation’s energy grid to ultimately benefit the U.S. economy. SETO is funding these larger industrial research and demonstration awards in order to accelerate de-risking and commercialization. SETO’s mission is to accelerate the development and deployment of solar technology to support an equitable transition to a decarbonized electricity system by 2035 and decarbonized energy sector by 2050. Achieving this goal will support the nationwide effort to meet the threat of climate change and ensure that all Americans benefit from the transition to a clean energy economy. — Award and cost share amounts are rounded and subject to change pending negotiations — Project Name: A Three-Phase Commercial Solar String Inverter with DC Battery Interface Based on Silicon Carbide and Planar Magnetics Location: Broomfield, CO DOE Award Amount: $500,000 Cost Share: $125,000 Project Summary: This team is developing a new inverter technology based on a silicon carbide transistor and high-frequency planar magnetics that can significantly lower the cost and size of grid-tied inverters. This inverter can be manufactured in the United States and interact with battery energy storage. Project Name: Safety Connectors for Mitigating PV System Arc Faults and Fires Location: Albuquerque, NM DOE Award Amount: $900,000 Cost Share: $225,000 Project Summary: This team aims to produce self-extinguishing PV connectors that will prevent fires in PV systems. The products will comply with national fire codes and be tested for mass production. Project Name: Integrated, Non-Metallic Floating PV System for Resiliency, Corrosion Resistance, and Safety Location: Livermore, CA DOE Award Amount: $1.6 million Cost Share: $400,000 Project Summary: This project will improve floating PV systems, making them more resilient to wind and waves. The lightweight, integrated PV systems will enable reduced mooring costs and faster installation for the floating devices. Project Name: Cost-Effective Primary Heat Exchanger for Gen3 CSP Systems Location: Waimanalo, HI DOE Award Amount: $600,000 Cost Share: $140,000 Project Summary: This project aims to de-risk an innovative heat exchanger for use in Generation 3 concentrating solar-thermal power (Gen3 CSP) systems. The technology uses high-temperature, high-pressure compatible materials with a design that is five times thinner than traditional heat exchangers, enabling significant reductions in material usage and costs. Project Name: Retractable Solar Modules for Greenhouses and Beyond Location: Mountain View, CA DOE Award Amount: $1.4 million Cost Share: $500,000 Project Summary: This project is developing and commercializing a foldable PV solar screen with variable shading and output power for controlled environment greenhouses. The lightweight, transparent screens can be retracted on demand and incorporate advanced light diffusion capabilities, creating a uniform shade under the screens while also producing electricity. Project Name: Low-Cost, High-Frequency Inverter Development for Utility Scale PV Location: Potsdam, NY DOE Award Amount: $1.2 million Cost Share: $300,000 Project Summary: Mission Drives is developing an inverter to switch electricity input 100 times faster than conventional products using silicon carbide and gallium nitride wide bandgap components. This approach results in a smaller, lighter, more efficient, and lower cost product. Project Name: Novel PV Array System Design to Accelerate Solar Deployment, Reduce Levelized Cost of Electricity, Reduce Land Use Competition, and Increase Siting Flexibility Location: Palo Alto, CA DOE Award Amount: $1.6 million Cost Share: $540,000 Project Summary: This project will develop, demonstrate, and validate a novel ground-mounted PV system design along with balance-of-system components and an installation methodology and equipment. Together, these innovations will enable highly automated installation of utility-scale PV at high speed. Project Name: High Performance Superstrate for CdTe Modules Location: Cheswick, PA DOE Award Amount: $1.6 million Cost Share: $1.1 million Project Summary: This team aims to improve the power output of cadmium telluride modules through a high-performance superstrate, which is the glass on which a solar module is built when the light will pass through the glass in the final configuration of the module. This project will integrate multiple performance increasing components into a single superstrate. Project Name: Efficiency and Energy-yield Improvement of CdTe-based Tandem Solar Modules Location: Perrysburg, OH DOE Award Amount: $7.3 million Cost Share: $7.3 million Project Summary: This project is developing a cadmium telluride-silicon tandem module—a new residential rooftop product that is more efficient than silicon or thin-film modules on the market. The goals are to improve the tandem module’s efficiency and advance the understanding of climate-dependent specific energy yield and reliability. Learn more about the Solar Energy Technologies Office’smanufacturing and competitiveness research, funding programs, andopen funding opportunities. Committed to Restoring America’s Energy Dominance. Follow Us
Norwegian researchers have developed a multi-pyranometer method to more accurately estimate global tilted irradiance (GTI) in the Arctic by separating beam, diffuse, and reflected solar components. Validated in the world’s northermost settlement, the approach was found to outperform conventional models in high-latitude conditions and improve PV system design for extreme environments. The GLOB installation Image: The University Centre in Svalbard A research team from Norway has proposed a new method to estimate global tilted irradiance (GTI) in the Arctic. The approach uses measurements from a 25-pyranometer array developed by the team to reconstruct the components of solar radiation: direct beam, diffuse sky radiation, and ground-reflected irradiance. These components are then used to calculate solar irradiance for any tilt and orientation. “Our multi-pyranometer instrument GLOB was used for the first time in the Arctic, where the sun is low on the horizon, to provide a precise picture of the solar energy potential on inclined planes,” lead author Arthur Garreau told pv magazine. “We have since also installed it at a site where a PV plant is planned in the coming years.” The project site is located in Longyearbyen, the world’s northernmost settlement, situated roughly midway between mainland Norway’s northern coast and the North Pole. According to the researchers, conventional GTI models often perform poorly at high latitudes due to low solar elevation angles, strong snow reflectance, and reliance on empirical models developed for mid-latitude conditions. “The Longyearbyen project will be the world’s northernmost solar PV plant,” Garreau added. “Our goal is to support project stakeholders in the design phase by providing accurate data on solar energy potential on the selected inclined plane.” GLOB consists of 25 silicon-cell pyranometers mounted on a geometric structure, with each sensor oriented at a different tilt and azimuth to capture incoming radiation from across the sky. An additional downward-facing sensor measures reflected irradiance from the ground. Image: The University Centre in Svalbard By capturing irradiance from multiple angles simultaneously, the system provides a detailed characterization of incoming solar radiation. The measurements are combined using a least-squares inversion to linearly estimate the direct and diffuse components of solar irradiance. In a second, nonlinear estimation approach, the same dataset is also used to derive ground reflectivity. Once these components are determined, a transposition model is applied to calculate global tilted irradiance (GTI) for any desired surface tilt and orientation. However, the researchers did not always rely on all 25 pyranometers. Suspecting that a higher number of sensors could introduce noise, and aiming to assess the potential for a lower-cost configuration, they tested combinations of 3, 4, 5, 9, 13, and 25 pyranometers under both linear and nonlinear processing schemes. When validated against high-quality reference data from a Baseline Surface Radiation Network (BSRN) station, the 13-pyranometer nonlinear configuration delivered the best overall performance, with a normalized root mean square error (nRMSE) of around 36% for beam irradiance and 23% for diffuse irradiance. “We were surprised by the accuracy that a five-pyranometer setup provided,” lead author Arthur Garreau noted. With only five sensors and a linear inversion method, the system achieved an nRMSE of around 38% for beam irradiance and 23% for diffuse irradiance. The results were benchmarked against conventional decomposition models and consistently showed improved accuracy. Using the optimal 13-pyranometer nonlinear configuration, the team then calculated GTI for Adventdalen, near Longyearbyen. The results indicate that, for monofacial systems, peak irradiance occurs at a tilt of around 45° facing south. For bifacial configurations, the highest values were found at a tilt of approximately 70°, with south and southeast orientations. “We also found that the solar energy potential at high latitudes for bifacial planes is near-optimal across a wide range of azimuths and for inclination angles between 60° and 90°,” Garreau concluded. “This provides greater design flexibility for PV installations in harsh Arctic environments.” The novel approach was described in “Improving solar energy estimates for tilted planes in the Arctic using a multi-pyranometer array,” published in Solar Energy. Researchers from Norway’s University Centre in Svalbard and the Norwegian University of Science and Technology have contributed to the study. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. More articles from Lior Kahana Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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The 204MW Zwartowo solar power plant has entered the Polish balancing energy market, a first in the country, according to German PV developer Goldbeck Solar. The project was a joint cooperation between Goldbeck Solar, responsible for the project’s development, construction and asset management, along with Polish trading energy company Respect Energy, which will trade the Zwartowo PV plant in the balancing market. Get Premium Subscription Even though balancing services are well established for conventional power plants and selected wind farms, large-scale solar PV plants have faced significant technical, regulatory and operational barriers preventing their participation, according to Goldbeck Solar. In the case of the Zwartowo solar power plant, due to its installed capacity, it is legally required to qualify for balancing services. However, the entry requirements for solar PV plants are “particularly stringent and go well beyond standard criteria for participation in electricity markets”, explained Goldbeck Solar. The PV project required 14 months to go through the qualification process and involved close coordination with grid operators, regulatory authorities and market participants. “The requirements are very harsh, especially for solar plants due to the intermittent nature of production and dependence on weather conditions,” said Affan Ahsan, Head of Asset Management at Goldbeck Solar. “Balancing markets were not designed with large‑scale photovoltaics in mind. Qualification requires precise controllability, very high data quality, reliable forecasting, as well as robust operational and legal processes.” Moreover, participating in the balancing market helps reduce curtailment risks, improve dispatch predictability and strengthen resilience against market volatility. Goldbeck’s internal modelling also suggests that PV assets can achieve up to 10% short-term revenue upside by actively bidding into ancillary service markets, while long‑term gains sit at around 4%. “Completion of the PV Zwartowo balancing services qualification is an important milestone not only for Respect Energy, but for the entire market. It proves that renewable energy sources can actively support system flexibility and respond to market needs,” said Karol Wolański, Head of Flexibility and Aggregation at Respect Energy. The neighbouring country of Germany witnessed its first ground-mounted solar PV plant prequalify to participate in grid balancing mechanisms last year. The 37.4MWp Schkölen solar project, a collaboration between German PV developer Enerparc’s subsidiary Sunnic Lighthouse, Nordic electricity company Entelios and transmission system operator 50Hertz, was prequalified for automatic frequency restoration reserve (aFRR) services in November and marked a “paradigm shift” for the energy system, as Sunnic Lighthouse told PV Tech Premium in November 2025. Other European countries, such as Spain, have also started allowing renewables to provide services that were previously restricted to conventional power plants. As a result of last year’s Iberian blackout (subscription required), the Spanish government passed legislation that allowed renewables, including solar PV plants, to participate in voltage control services, which began in March of this year.
Christ the King International School has inaugurated a solar photovoltaic system as a major step towards ensuring energy sustainability in the school. The installation is a significant milestone, as the school becomes the first Catholic institution in the country to benefit from the nationwide renewable energy initiative by the National Catholic Secretariat. This is the first phase of the school’s ongoing redevelopment project. The Metropolitan Archbishop of Accra, Most Rev. John Bonaventure Kwofie, inaugurated the project together with the Bishop of the Keta-Akatsi Diocese, Most Rev. Gabriel Edoe Kumordji, S.V.D., who is also the Board Chairman of Lumen Energy Company Limited, the special purpose vehicle set up by the Catholic Church to implement a nationwide solar energy initiative of the Ghana Catholic Bishops’ Conference to power 4,000 Catholic institutions in Ghana as part of a Renewable Energy Project. Also at the ceremony was the Local Manager of the project, Rev. Fr. Ebenezer Akesseh; the headmistress, Portia Felice Mensah; representatives from Lumen Energy and Huawei Ghana; officials from the Catholic Standard, as well as staff and students of the school. A solar photovoltaic (PV) system is a renewable energy setup that converts sunlight directly into electricity using semiconductor materials, typically silicon. The solar panels being laid It generates direct current power when sunlight hits PV cells, which an inverter then converts into usable alternating current as power. This installation forms part of a broader national programme established through a Memorandum of Understanding (MoU) between Lumen Energy Company Limited and Huawei Ghana. The initiative seeks to deploy solar energy systems across approximately 4,000 Catholic institutions in Ghana under the Ghana Catholic Bishops’ Conference Renewable Energy Project. Beyond delivering reliable and cost-effective power, the solar installation represents a strong commitment to sustainability and responsible resource management. It places the school at the forefront of a transformative journey. One that brings together education, innovation, and environmental stewardship for the benefit of future generations. Our newsletter gives you access to a curated selection of the most important stories daily.Don’t miss out. Subscribe Now.
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Hardware chain Bunnings is making a play for a slice of the home energy market with a subscription offer for rooftop solar and household battery energy storage systems. Image: Bunnings Hardware giant Bunnings has announced a new partnership with digital energy management company Intellihub that introduces a new way for customers to buy and install rooftop solar energy and battery packages for their homes without the initial outlay. Bunnings said the new Zelora platform allows customers to purchase and install rooftop solar and battery energy storage systems through a monthly subscription plan. The subscription offer provides a range of system options that can be accessed online and supported by an energy management app. It will use solar, inverter, and battery products supplied by Das Solar, SigEnergy and GoodWe. Zelora will be operated by Intellihub, which will supply and install the solar and battery systems, and manage the smart technology that helps to optimise the service that is now available as part of a trial across Newcastle and greater Sydney in New South Wales. Intellihub Executive General Manager Australia Alastair McKeown said Zelora will streamline how customers can access and pay for residential battery and solar systems. “The Zelora partnership with Bunnings will remove the complexity and big upfront cost that often comes with solar and battery systems to make it easier for households to reduce their electricity bills,” he said. Zelora solar and battery packages are priced from $112 (USD 73.50) per month, or $15,058 over 10 years, for 3.96 kW of solar and 7.8 kWh of battery storage, up to $202/month ($27,157 over 10 years) for a 13.2 kW of solar and 23.4 kWh of battery storage. Subscriptions for batteries start at $80 per month for a 7.8 kWh system, up to $144/month for a 23.4 kWh system. It is also offering solar only packages that can be purchased outright, ranging from $4,470 for a 3.96 kW system through to $7,940 for 13.2 kW of solar. Bunnings Chief Operating Officer Ryan Baker said the Zelora offering tackles the affordability and complexity often associated with renewable energy. “Many customers find home electrification complex and may not be aware of the benefits it can offer,” he said. “Zelora has been developed to simplify the home battery and solar opportunity for customers in a cost-effective way.” The launch of Zelora comes after Bunnings recently launched an electric vehicle (EV) charging range available instore and online. The hardware giant is also trialling EV charging stations at selected store carparks in New South Wales, Victoria, Western Australia and New Zealand. Bunnings earlier this year announced it has achieved its 100% renewable electricity target milestone across its Australian and New Zealand store network, as part of its commitment to achieve net zero Scope 1 and 2 emissions by 2030. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. More articles from David Carroll Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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Newsroom In a move that will come as a relief to thousands of households across Cyprus, Parliament has stepped in to stop extra solar energy from simply disappearing. In a unanimous vote, MPs approved a regulation to ensure that surplus electricity produced by residential photovoltaic systems will no longer be wiped out. Instead, that unused energy will now be kept on record, at least until the government decides how it should be used or credited back to consumers.
But beyond the immediate fix, the debate has exposed a bigger issue: Cyprus’ energy system is struggling to keep up with its own solar success. For many families, this isn’t just technical; it’s personal. Over the past months, households that invested in solar panels, often taking out loans to do so, saw their extra electricity effectively reduced to zero when it couldn’t be absorbed by the grid. The decision sparked frustration, with many questioning why energy they produced was going to waste while their electricity bills remained high. Now, Parliament is trying to fix that. Lawmakers said the change corrects what many described as a clear injustice affecting around 100,000 households. The new approach means that any surplus energy will be preserved rather than erased, buying time for a proper system to be put in place. The responsibility now shifts to the government. The Council of Ministers will decide how that stored energy will be handled, whether it will be credited back to users, carried forward for future use, or managed in another way. Early signals from the Energy Ministry suggest that affected consumers, particularly those under older agreements, could see their lost units restored. At the same time, the law was tweaked to address constitutional concerns raised by the president, mainly around the balance of powers and potential financial implications. But beyond the immediate fix, the debate has exposed a bigger issue: Cyprus’ energy system is struggling to keep up with its own solar success. Despite the island’s ideal weather for renewable energy, officials admit the grid is not yet fully equipped to handle the growing volume of solar power being produced. In some cases, cutting off household solar generation has become the default solution, something critics say defeats the whole purpose of investing in renewables. MPs across party lines stressed that this can’t continue, warning that without a clear long-term plan, public trust in green energy could take a hit. BUILT BY BDIGITAL | ADA CMS | POWERED BY WEBSTUDIO | TERMS & CONDITIONS
Ready to get up to 3 free quotes? Get up to 3 free quotes for solar, batteries, EV chargers or hot water heat pumps GET MY QUOTES Most solar owners judge their system by a simple measure: how much energy it produces over the day. If the total looks good, it was a good day. If it’s down, something must be wrong — but that’s not always the full story. To understand why, it helps to look at how solar output actually behaves in real time — something solar forecasters track closely. If you’ve ever checked your monitoring app and wondered why your solar output jumps up and down on an otherwise decent day, you’re seeing something quite normal — output can rise and fall sharply along the way, with dips and recoveries that don’t always follow a smooth pattern. Solar output rarely moves in a smooth line, even on stable days. Those fluctuations are easy to see in the output graph, just not in the way most people interpret performance. Solar output on a typical “good” day can still include short, sharp dips — even when overall generation remains strong. Time of day and season are the predictable part of solar irradiance. What changes in real time is how that signal is shaped by the atmosphere, particularly cloud cover. That variability is what solar forecasting systems are designed to model. Companies like Solstice AI and Solcast use that modelling to track how output changes minute by minute, rather than just what the total looks like at the end of the day. This is why forecasting systems focus on questions like what happens at 10:17am when a cloud passes, how quickly output drops and recovers, and how accurate a five-minute-ahead forecast really is. Forecasters use this information for real-time grid and market decisions. At household level, the same output fluctuations show up in smaller but still meaningful ways — especially around when energy is used, stored, or drawn from the grid. “Forecasting the output of rooftop solar PV systems is inherently complex, as it depends on both atmospheric conditions and site-specific factors,” Dr Julian de Hoog of Solstice AI says. The challenge starts with estimating how much solar irradiance reaches a given location. While time of day and season are predictable, cloud behaviour drives most of the uncertainty in short-term forecasting. Days with uniform conditions — either clear sky or full cloud cover — are easier to predict. Intermittent cloud, especially small, fast-moving “spot clouds”, is much harder. These can be too small to be resolved in satellite imagery, yet still cause sharp fluctuations in solar generation. Passing cloud cover can cause short, sharp changes in solar output, even when conditions appear stable. At this time of year, additional factors can make forecasting more difficult. In northern Australia, convective cloud formation can remain active into autumn, with clouds developing rapidly and with little warning. In southern regions, morning fog becomes more common and can reduce predictability in the early part of the day. From a forecasting perspective, this makes short-term output difficult to predict, while at household level it can still look like a fairly normal solar day. Until recently, short-term changes in solar output haven’t mattered much for most households. If the daily total was strong, brief dips during the day weren’t especially important. But that is starting to change as more homes use solar in real time rather than just as a bill offset. Falling feed-in tariffs, along with the rise of electric vehicles, batteries, and time-of-use pricing, are shifting attention from exporting energy to using it as it’s generated. Charging EVs during the day, running appliances directly from solar, storing excess in batteries, and avoiding grid imports during peak pricing all make timing more important than it used to be. In some cases, such as demand-based tariffs, a short spike in grid usage during a dip in solar output can have a much bigger impact on costs than you might expect, because charges are based on peak demand rather than total energy. A passing cloud might barely change the daily total, but it can still cause output to drop at exactly the wrong moment — triggering grid imports when they weren’t expected. A brief drop in solar output can trigger an immediate rise in grid usage. Not really — but understanding the difference between real-time changes and daily totals helps. Forecasters focus on accuracy over time because their outputs feed into grid operations and market decisions at scale. Solar owners focus on outcomes across a day, where small fluctuations usually don’t have much financial impact. But as more households rely on solar in real time, that gap is narrowing. Because once you start using solar as it happens rather than just what it produces by sunset, short-term changes start to matter more. The point isn’t choosing between daily totals and real-time behaviour — it’s understanding both. For most households, the daily total will still be the headline number. That hasn’t changed. As appliances, batteries, and electric vehicles become more closely tied to when solar energy is available, short-term fluctuations start to matter in practical ways they didn’t before. That doesn’t mean tracking every dip or watching every cloud. It just means having a rough sense of when your solar is performing well — and aligning major energy use with those periods where you can. Adding a home battery storage system can also help to ensure you can ride out those short-term dips without drawing from the grid. For a deeper breakdown of how solar output, power, and energy fit together, our guide on energy vs power (kW vs kWh) is a good place to start. Sign up for our weekly newsletter!
A solar installer and electrician in a previous life, Kim has been blogging for SolarQuotes since 2022. He enjoys translating complex aspects of the solar industry into content that the layperson can understand and digest. He spends his time reading about renewable energy and sustainability, while simultaneously juggling teaching and performing guitar music around various parts of Australia. Read Kim’s full bio. Please keep the SolarQuotes blog constructive and useful with these 5 rules: 1. Real names are preferred – you should be happy to put your name to your comments. 2. Put down your weapons. 3. Assume positive intention. 4. If you are in the solar industry – try to get to the truth, not the sale. 5. Please stay on topic.
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You have reached your maximum number of saved items. Remove items from your saved list to add more. Save this article for later Add articles to your saved list and come back to them anytime. A four-fold surge in residential battery uptake is being hailed as a transformative moment for the electricity grid, offering hopes of lower prices by absorbing more of the excess renewable energy from solar panels during the day to power homes after sunset. Australian households bought 183,000 battery units in the second half of 2025, a figure four times higher than at the same time a year earlier and almost as many as the previous five years combined, new figures reveal. The uplift, which industry leaders described as “phenomenal”, comes after the Albanese government made large rebates available last year to anyone buying a battery system to stash power from their rooftop solar panels. The rebates trim thousands of dollars off the upfront cost. Australia has long ranked as a world leader in per-person solar uptake, with more than 4 million homes – or one in three – fitted with rooftop solar panels. The new figures from the Clean Energy Council, to be released on Wednesday, show rooftop solar has grown to 28 gigawatts of capacity in the energy grid, eclipsing that of the national fleet of coal-fired power stations (22.5 gigawatts). “Our biggest power station now resides on the rooftops of more than 4.3 million households, which is helping to drive downward pressure on power bills for consumers and businesses,” the industry group’s chief executive, Jackie Trad, said. However, until recently, just one in 40 homes also had a battery, which has led to a problem: all those solar panels have been making far too much electricity in the middle of the day when the sun is brightest, and hardly any when people return home, turn on their lights and operate appliances, which causes wholesale prices to spike. The rising uptake of home batteries – most of which use lithium-ion technology like those in smartphones, cordless drills and electric cars – would enable more homes with solar panels to store their free power and use it at peak times for demand in the afternoons, Energy Minister Chris Bowen said. This, he said, would take pressure off the grid and curb volatile price swings for all energy users. “More Australians are taking control of their power bills and using their own clean, cheap energy when they need it,” Bowen said. “Home batteries deliver real, lasting cost-of-living relief for Aussie households, while working to make the energy grid fairer, more affordable and more reliable during peak demand times.” Electricity bills have gone up hundreds of dollars a year across parts of Australia since 2022, largely due to the fallout from Russia’s invasion of Ukraine boosting coal and gas prices and adding to the cost of generating power. The rollout of new renewable projects and transmission lines is also lagging the speed needed to compensate for the closures of coal-fired power stations. But there are signs that installing more renewables and batteries is starting to help suppress prices, experts say. Wholesale electricity costs – what retailers pay for power before selling it to customers – fell sharply in eastern Australia in the final three months of last year as record contributions from renewables and batteries reduced the need to call on fossil fuel-powered generators and hydroelectric dams to plug critical supply gaps. Tristan Edis, the head of analysis at energy consultancy Green Energy Markets, said the scale of home battery installations was so significant that it could force down electricity prices if it remained on trend. “If the scale of capacity being installed can be maintained for the next five years it should severely curtail the degree to which gas generators can spike up wholesale market prices,” he said. Authorities warn that while adding batteries can reduce overall demand in the grid, all of that stored energy needs to be better “orchestrated” to cut the cost of the energy transition for as many people as possible. The Australian Energy Market Operator is urging retailers to spur greater participation in “virtual power plants”, whereby power providers give customers bill credits in exchange for being able to aggregate the capacity of thousands of batteries at once to address imbalances in the grid and keep the network stable. Alongside batteries, the deployment of more gas-powered generators and larger storage assets, such as hydropower, will also remain critical to backing up renewables, the operator says, especially for periods of elevated demand, and prolonged stretches of low wind and sunlight. Even today’s most powerful grid-scale batteries still exhaust their stored energy in two to four hours of maximum output, minimising their ability to plug longer-lasting shortfalls. The Business Briefing newsletter delivers major stories, exclusive coverage and expert opinion. Sign up to get it every weekday morning. You have reached your maximum number of saved items. Remove items from your saved list to add more. More:
Peru has a pipeline of 13 solar power projects with Final Generation Concessions under the National Interconnected Electric System (SEIN), representing 2,402 MW of planned capacity and expected investment of US$1.8 billion, according to the Ministry of Energy and Mines (MINEM), through its General Directorate for Energy Efficiency (DGEE). The projects are expected to strengthen national energy security, support grid integration, and accelerate Peru’s energy transition towards cleaner power sources. Peru currently has 1,088 MW of installed solar PV capacity. With the phased commissioning of the new projects, national solar capacity is projected to reach 3,490 MW by 2028—more than tripling current levels and significantly expanding renewable electricity supply. Southern Peru is emerging as the country’s solar powerhouse, with the region of Arequipa leading deployment. Arequipa accounts for the largest share of the pipeline, consolidating its position as Peru’s main photovoltaic generation hub. The region benefits from some of the highest solar irradiation levels in Latin America, making it particularly attractive for solar PV investment. Moquegua and Ica also continue to expand their role in utility-scale renewable energy, while the 130 MW Kuarachi Solar Plant in Loreto is expected to improve electricity supply in Peru’s Amazon region through clean energy generation. According to the DGEE, the territorial distribution of these projects reflects a strategy to harness Peru’s strong solar resource while enhancing the resilience and decentralisation of the national power system. The expansion also aligns with broader efforts to increase renewable energy penetration, attract investment in renewables and improve long-term energy security amid rising electricity demand. MINEM reiterated its commitment to advancing renewable energy development and supporting investments that contribute to a cleaner, more secure and decentralised electricity system. by Emilia Lardizabal Keep reading New grid access capacity maps published by Spain’s CNMC reveal mounting constraints in both demand and generation connections. While the tool improves transparency, industry experts warn the congestion reflects stalled projects and structural bottlenecks that are already shaping investment decisions and threatening the pace of renewable energy deployment. by Lucia Colaluce Keep reading Executives from EGE Haina, AES Dominicana, InterEnergy and CMI agreed on the urgent need to address renewable curtailment, advance battery regulation and tackle challenges linked to transmission and system sustainability. With more than 120,000 MWh of renewable energy curtailed so far in 2026 and a project pipeline targeting nearly 2 GW of solar PV, the focus is shifting from expanding capacity to integrating flexibility, energy storage and market rules. by Emilia Lardizabal Keep reading With nearly 38 GW of oversubscribed capacity competing for 7.5 GW, Mexico’s Federal Electricity Commission has revised the timetable for its mixed tender and set contract signing for 8 June. The market expects prices between USD 35 and 70/MWh, alongside mandatory storage requirements and stricter financial thresholds. by Emilia Lardizabal Keep reading New grid access capacity maps published by Spain’s CNMC reveal mounting constraints in both demand and generation connections. While the tool improves transparency, industry experts warn the congestion reflects stalled projects and structural bottlenecks that are already shaping investment decisions and threatening the pace of renewable energy deployment. by Lucia Colaluce Keep reading Executives from EGE Haina, AES Dominicana, InterEnergy and CMI agreed on the urgent need to address renewable curtailment, advance battery regulation and tackle challenges linked to transmission and system sustainability. With more than 120,000 MWh of renewable energy curtailed so far in 2026 and a project pipeline targeting nearly 2 GW of solar PV, the focus is shifting from expanding capacity to integrating flexibility, energy storage and market rules. by Emilia Lardizabal Keep reading With nearly 38 GW of oversubscribed capacity competing for 7.5 GW, Mexico’s Federal Electricity Commission has revised the timetable for its mixed tender and set contract signing for 8 June. The market expects prices between USD 35 and 70/MWh, alongside mandatory storage requirements and stricter financial thresholds. A leading media group in digital marketing, strategic communication, and consultancy specialized in renewable energy and zero-emission mobility, with a presence in Latin America and Europe. We focus on helping companies position their brand in key markets, connecting with the main decision-makers in the energy transition.
For full functionality of this site it is necessary to enable JavaScript. Here are the instructions how to enable JavaScript in your web browser. Sectors Published by Abby Butler, Editorial Assistant Energy Global, The hep global group (hep global), a specialist in the development of solar projects, has started construction on a 4.1 MWp solar park, including integrated battery storage, in Bavaria, Germany. The solar park is being built on an area of ??approximately 3.5 hectares near a railway line in the Bavarian town of Biessenhofen, southwest of Munich. Grid connection and commissioning are planned for 2026. The solar park will generate approximately 4.7 GWh of climate-friendly electricity annually, enough to supply around 1380 average German households. A high-performance battery storage system with a storage capacity of 2.8 MWh and an output of approximately 1.4 MW expands the plant and ensures maximum energy efficiency. This so-called green energy storage system enables the intermediate storage of surplus energy and its feed-in to the grid as needed – even during periods of low solar irradiance. In this way, the Biessenhofen solar park contributes to a more stable and sustainable energy supply. The solar park is the second result of the strategic partnership between hep global and the photovoltaic specialist, Volllast GmbH. In January 2026, hep global announced the development of an 8 MWp solar park in Schongau. Further projects in the region are planned for 2026. The hep global group, with locations in several solar markets worldwide, has been active in solar project development in Germany again since 2022. Martin Vogt, Chief Project Officer, noted: “Over the past 15 years, hep global has gained extensive experience in developing solar projects in Japan, the US, and Canada. The strategic decision to refocus on project development in Germany led to successful project sales as early as 2025. 2026 will be characterised by the construction phase of these projects – primarily in Bavaria and Baden-Württemberg.”
Something went wrong DAEGU, South Korea, April 23, 2026 /PRNewswire/ — Amid growing demand in Korea for efficient, reliable, and advanced cell technologies, Tongwei Solar appeared at Green Energy Expo 2026. On April 23, the company held an on-site presentation on advanced cell technologies, highlighting its TNC series high-efficiency cells and the latest progress of the TNC 3.0 multi-cut cell in product performance, technology advancement, and value delivery. Responding to the Korean market's focus on high-efficiency generation, stable mass production, and application value, Tongwei Solar delivered an "Advanced Cell Technology Overview" presentation at the exhibition venue, sharing the technology pathway, product capabilities, and application potential of its TNC series high-efficiency cells. As a key focus of the exchange, Tongwei Solar introduced the product evolution of its TNC 3.0 multi-cut cell. Integrating TPE, multi-cut, and Poly Tech technologies, and moving relevant optimization steps forward to the cell side, the product further reduces loss and enhances performance to support downstream value delivery. Through this coordinated approach, the TNC 3.0 multi-cut cell delivers module power gain of 10W+, bifaciality boost of 5%, and conversion efficiency of over 26.3%, creating greater value for high-efficiency modules. Tongwei Solar, a core subsidiary of Tongwei Co., Ltd., focuses on the R&D and manufacturing of high-efficiency crystalline silicon solar cells. The company has over 150GW of cell production capacity, more than 400GW in cumulative shipments, and has ranked No. 1 globally in cell shipments for nine consecutive years, according to InfoLink Consulting. Backed by the Tongwei Global Innovation R&D Center, Tongwei continues to advance solar cell technology and drive PV innovation. In September 2025, Tongwei Solar's Meishan company was recognized as the world's first Lighthouse Factory in the photovoltaic cell industry. Supported by lighthouse-level intelligent manufacturing, cell-level traceability, and full-process quality control, Tongwei Solar continues to strengthen product stability and reliability while providing rapid response, technical exchange, and application support to overseas customers. With strengths in products, R&D, manufacturing, and quality, Tongwei Solar is bringing the Korean and global markets a more efficient, reliable, and long-term solar choice. For more information, please visit: https://en.tongwei.cn/
Over 1.3 million readers this year! Over 1.3 million readers this year! Cap City News Cheyenne, Wyoming Community News Stream. by Dustin Bleizeffer, WyoFile Months after cancelling its massive 600-megawatt, $729 million Jackalope wind energy project in Sweetwater County, NextEra Energy Resources is advancing a handful of other renewable energy projects in the state. The company recently inked an agreement that secures access to Black Hills Energy’s electric transmission system for 200 megawatts of “wind power” generation still under development on the state’s east side, according to a federal filing. The agreement, which reserves space on Black Hill’s Pumpkin Buttes-Windstar 230 kilovolt line, doesn’t specify a particular NextEra project. However, the Florida-based company operates wind farms in Laramie and Converse counties — both with the potential for expansion. NextEra is also advancing a wind, solar and battery storage proposal in Platte County dubbed the Chugwater Energy Project. It consists of 300 megawatts of wind-generated power capacity, 150 megawatts of solar and 150 megawatts of battery storage capacity, the company says. In Albany County, NextEra is developing the 160-megawatt Sailors Solar project on property leased from the city of Laramie. One megawatt is enough electricity to power about 750 homes. While the industry has faced uncertainty, the “interconnect” agreement with Black Hills is a sign of life for the future of industrial-scale renewable energy development in Wyoming. PacifiCorp — parent company to Rocky Mountain Power, Wyoming’s largest electric utility — recently wiped new wind and solar from its future plans in the state. Though the utility has built its own renewable energy facilities here, it has also frequently called upon other companies to develop wind farms with the offer to potentially purchase the power they produce. It’s unclear what PacifiCorp’s exit might portend for future renewable energy buildout in Wyoming, according to industry insiders who have spoken to WyoFile. There are federal policy headwinds, too. The “One Big Beautiful Bill Act” accelerates the phaseout of federal tax credits for wind energy. Those tax credits, according to PacifiCorp, reduced the cost of building wind energy by about 30%. The Trump administration has also ordered federal agencies to pause permitting for some renewable energy. Industry analysts have speculated that’s one reason NextEra abandoned its Jackalope wind energy project on the west side of the state. The project spanned some federal lands managed by the Bureau of Land Management. Still, several renewable energy projects appear to be moving forward. The massive $5 billion, 3,550-megawatt Chokecherry and Sierra Madre Wind Energy Project is under construction in Carbon County. It will rival the SunZia wind project in New Mexico as the largest onshore wind energy facility in North America, according to Power Company of Wyoming. Member-owned electric co-ops are getting in on the action, too. Though on a smaller scale, Powder River Energy Corporation plans to build a solar power generation and battery storage facility in northeast Wyoming. The LaBelle Prairie Project would generate 1.5 megawatts of solar power connected to a battery system to store up to 5 megawatts of energy, according to the company. Renewable energy developers still must overcome local opposition to clear permitting hurdles at the state and county levels. NextEra won a permit in February from the Wyoming Industrial Siting Council for the Chugwater project. Next, the project goes before the Platte County Planning and Zoning board, then the Board of Platte County Commissioners. “This is all part of the ‘wind wall’ that people are talking about,” Keith Miller told WyoFile. The Platte County resident has concerns about the Chugwater project. “They need to consider the broader implications of all of these projects.” The company is asking county officials to rezone some areas from ranching, agriculture and mining to industrial use. It’s also requesting special use and variances for the project. The matter goes before the planning and zoning board on May 13, and before the commission on a to-be-determined date later in May. This article was originally published by WyoFile and is republished here with permission. WyoFile is an independent nonprofit news organization focused on Wyoming people, places and policy.
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Editor 23 April 2026 THE PV Fire Intelligence Network – a dedicated network chaired by the Building Research Establishment – is now inviting professionals from across the fire prevention, solar energy and construction sectors to share their experiences of the safety of solar photovoltaic (PV) panels. This research is a key step forward in the PV Fire Intelligence Network’s mission to create a national conversation that will improve the safety of solar PV panels. The responses will help the network to establish reliable data on the causes and consequences of solar PV-related fires and recommend solutions to reduce the risk posed by them in the future. The research covers topics including work practices, near misses and fire incidents: *work practices: general installation and maintenance practices across the solar PV industry *near misses: events that could have resulted in a fire, but were prevented before an incident occurred *fire incidents: all solar PV-related fire incidents The online questionnaire will be open until 30 June. Participants are invited to complete only the sections relevant to their expertise and experience. All responses will be treated as confidential to support open and honest input and to help ensure the findings deliver the greatest possible insight and value. Participants can visit https://www.pvfin.org/ for more information and/or send an e-mail to [email protected] Identifying the threats Raman Chagger, principal consultant at the Building Research Establishment and lead for the PV Fire Intelligence Network, explained: “The results from this questionnaire will enable us to identify the threats and corresponding Best Practice for the fast-evolving solar PV sector.” Chagger added: “Ensuring safety in solar PV systems is essential if we’re going to encourage their adoption and, ultimately, make the successful transition to clean energy. Participation from industry professionals is essential to achieve this goal.” The PV Fire Intelligence Network was established last October as a Steering Group of leading organisations to analyse the fire safety of solar PV systems. Solar PV and component manufacturers, fire experts and solar safety solution providers form the network. Members include the MCS Company, the Fire Industry Association, the CGM Group UK, Enphase Energy, IMO Precision Controls, PVStop, SolarEdge Technologies, ArcBox (a division of Viridian Solar) and Solar Energy UK. Solar PV is a critical element of the UK’s green transition, increasing the need for up-to-date and reliable data on the fire risk posed by these systems to promote their take-up among homeowners, businesses and the public sector. 1/405 (1 to 10 of 4043)
Argentina is consolidating its position as a solar market in the region based on its technical maturity and improved financial conditions compared to previous years, after surpassing 7,900 MW of installed renewable capacity, of which more than 2,500 MW correspond to solar PV. “Argentina has matured very quickly from a technical standpoint, to the point that today it is at the forefront technically. Meanwhile, on the financial and macroeconomic side, we went through difficult moments with the country in terms of payment structures and a series of complexities, but today it is much more stable,” acknowledged Miguel Covarrubias, Sales Director LATAM at Jinko Solar. “So the market is mature, there is technical know-how and service expertise, which makes projects in the country highly viable both technically and economically,” he said during an interview held within the framework of Future Energy Summit (FES) Argentina. This scenario is already reflected in the company’s strategy, having supplied nearly 30% of all solar panels currently operating in Argentina’s Wholesale Electricity Market (MEM), representing 36% of installed photovoltaic capacity, according to official CAMMESA data. “Moreover, the conditions are in place in the country, and it is a priority market for us in LATAM, accounting for around 25% of what we supplied in the region last year,” Covarrubias noted. Watch the full interview with Jinko Solar at FES Argentina: https://youtu.be/GHccKrwFUJ8 In this context, the bankability of solar projects is increasingly linked to the profile of the technology supplier. “It is key,” Covarrubias said, explaining that banks prioritise manufacturers with strong technical and financial backing. At the same time, technological evolution continues pushing the boundaries of the industry. “Our core is to compete through technology and efficiency,” he said, referring to the new Tiger Neo 3.0 line, which allows outputs of 660–670 Wp in modules that previously reached around 620 Wp, without increasing their surface area. However, part of the market is still seeking even higher power outputs, introducing new challenges. “There is a 10–15% segment still looking for larger modules,” he explained, referring to panels reaching 730–735 Wp, although these involve greater logistical and installation demands. Despite these complexities, the local market has demonstrated adaptation capacity. A concrete example is the El Quemado solar park, developed by Argentina’s state-controlled energy company YPF in Mendoza. The project, which will reach 305 MW of installed capacity, already has 200 MW in operation and includes more than 550,000 panels. “We expected there would be more failures and breakages during installation, which did not happen,” Covarrubias pointed out, validating the performance of larger-format modules. Looking ahead, market growth will be driven by new opportunities in energy storage and regulation. Initiatives such as the AlmaSADI tender, which foresees adding 700 MW of BESS, together with the continuation of the Mercado a Término, are shaping an expansion scenario. Nevertheless, there are still aspects to improve. “There is room for improvement linked to transmission and batteries,” the executive said, concluding that these developments will make it possible to “further expand the penetration of renewable energy, particularly solar energy.” by Emilia Lardizabal Keep reading New grid access capacity maps published by Spain’s CNMC reveal mounting constraints in both demand and generation connections. While the tool improves transparency, industry experts warn the congestion reflects stalled projects and structural bottlenecks that are already shaping investment decisions and threatening the pace of renewable energy deployment. by Strategic Energy Keep reading Thirteen utility-scale solar projects with final generation concessions—mainly in southern Peru—are set to more than triple the country’s installed solar capacity by 2028, reinforcing energy security and accelerating the shift towards renewable energy. by Lucia Colaluce Keep reading Executives from EGE Haina, AES Dominicana, InterEnergy and CMI agreed on the urgent need to address renewable curtailment, advance battery regulation and tackle challenges linked to transmission and system sustainability. With more than 120,000 MWh of renewable energy curtailed so far in 2026 and a project pipeline targeting nearly 2 GW of solar PV, the focus is shifting from expanding capacity to integrating flexibility, energy storage and market rules. by Emilia Lardizabal Keep reading New grid access capacity maps published by Spain’s CNMC reveal mounting constraints in both demand and generation connections. While the tool improves transparency, industry experts warn the congestion reflects stalled projects and structural bottlenecks that are already shaping investment decisions and threatening the pace of renewable energy deployment. by Strategic Energy Keep reading Thirteen utility-scale solar projects with final generation concessions—mainly in southern Peru—are set to more than triple the country’s installed solar capacity by 2028, reinforcing energy security and accelerating the shift towards renewable energy. by Lucia Colaluce Keep reading Executives from EGE Haina, AES Dominicana, InterEnergy and CMI agreed on the urgent need to address renewable curtailment, advance battery regulation and tackle challenges linked to transmission and system sustainability. With more than 120,000 MWh of renewable energy curtailed so far in 2026 and a project pipeline targeting nearly 2 GW of solar PV, the focus is shifting from expanding capacity to integrating flexibility, energy storage and market rules. A leading media group in digital marketing, strategic communication, and consultancy specialized in renewable energy and zero-emission mobility, with a presence in Latin America and Europe. We focus on helping companies position their brand in key markets, connecting with the main decision-makers in the energy transition.
SAVE $1,300.01: As of April 23, the Jackery HomePower 3000 is on sale for $1,698.99 at Amazon. That’s a 43% discount on the list price. If you’re looking for whole-home backup, the Jackery HomePower 3000 is back on sale at Amazon. This portable power station can power pretty much anything, from your fridge to your laptop. As of April 23, the unit with solar panels is reduced by over $1,000, bringing the price down to $1,698.99 from $2,999. This Jackery device has a 3,600W output (7,200W surge) and 3,072Wh capacity, so it can keep essential household devices running during outages, often for many hours or even days. For seamless connection, it features a fast-switching UPS system that can take over within 20ms to help prevent interruptions to important equipment like security systems or medical devices. It includes a range of ports such as AC, USB-C, USB-A, and DC, plus an RV-ready output, so it can be used on the road, not just at home. It also supports multiple charging methods, including fast AC and hybrid charging, as well as solar, car, and generator options. And because it’s built with LiFePO4 battery technology, you know it’ll last for years. This is a limited-time deal at Amazon, so don’t miss out. TopicsAmazon Lois Mackenzie is a freelance reporter at Mashable. Over the years she has written for many publications, covering everything from the local news to the best pair of running shoes. You can find bylines in publications including Fit&Well, Metro, and Coach magazine, usually covering deals on everything from earbuds to TVs, or guides on how to beat your half marathon time. Lois also holds a Master’s degree in Digital Journalism from Strathclyde University and obtained a Master of Arts in English Literature at the University of Aberdeen.
0 Powered by : Poland headquartered PAD RES has commenced construction of three photovoltaic farms in Poland with a combined capacity of 133 MW. The projects are located in Krapkowice, Strzelce Opolskie and Gromadka. The Krapkowice project accounts for 90 MW and about 95,000 MWh of annual output. Strzelce Opolskie adds 18 MW with around 19,000 MWh per year. Gromadka contributes 25 MW with estimated yearly generation of 26,000 MWh. Combined output is expected to match annual electricity demand of about 47,000 households. PAD RES said the projects support expansion of its renewable generation platform.
Solar Power World By Kelly Pickerel | The Dept. of Commerce has released its preliminary antidumping duty (AD) amounts in an investigation on solar cell imports from India, Indonesia and Laos. The preliminary AD margins are 123.04% for all Indian producers, 35.17% for all Indonesian producers, and 22.46% for all Laotian producers. Combined with the preliminary countervailing duty (CVD) determinations, India has the highest AD/CVD rates of the three countries. The Alliance for American Solar Manufacturing and Trade, a group of domestic solar manufacturers, petitioned the government in July 2025 for an AD/CVD investigation, alleging that solar panel manufacturers had relocated their operations to India, Indonesia and Laos to avoid tariffs placed on imports from Cambodia, Malaysia, Thailand and Vietnam. The U.S. International Trade Commission (ITC) determined in August that the U.S. industry has been materially injured by imports from the three countries, and Commerce has been performing its own investigation into the matter. With the preliminary tariff amounts out now, the next date to look toward is Sept. 3, 2026, for the final duty determination from Commerce. A final decision from the ITC is then scheduled to come Oct. 19. Issuance of the AD/CVD orders would be one week later on Oct. 26. The Alliance, which includes First Solar, Mission Solar, Qcells and Talon PV, also filed a “critical circumstances” allegation in January 2026 with the Secretary of Commerce. The document said that imports from India, Indonesia and Laos have surged, activity that “strongly indicates that these imports are being rushed into the United States in an effort to avoid the imposition of antidumping and countervailing duties.” The Alliance requested an expedited critical-circumstances decision, which would impose duties retroactively on imports entered up to 90 days before the tariffs are announced. In its preliminary CVD determination, Commerce revealed varied critical circumstance decisions. In the preliminary AD decision, Commerce determined that critical circumstances did exist for Indian producers Mundra Solar, Kowa and Premier Energie, but not for all others. In Indonesia, Commerce determined that imports from Blue Sky and PT REC Solar Indonesia did not significantly increase but imports from all others did. Critical circumstances exist in Laos against all cell producers except Solarspace. Final determinations with the critical circumstances should be released alongside the final AD/CVD determinations. 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.
A church in Georgia has a new 70.11-kW solar system and a 41-kWh battery storage system which could generate and store enough electricity to save about $15,000 a year on its utility bills. There was no up-front cost to the congregation because of support from Hive Fund, Black Voters Matter, and Georgia BRIGHT. “New Bethel AME Church is demonstrating extraordinary leadership as the first Georgia BRIGHT Communities participant to integrate battery storage with their solar system, By embracing storage, they’re not only cutting costs and increasing resilience for their congregants and the surrounding community, but also showing how community organizations can play an important role in reducing costs and increasing resilience for the larger energy system,” said Alicia Brown, Director of Georgia BRIGHT. There is also a reference in the source to adding EV chargers to the solar power and energy storage mix. This is a potentially important benefit because during a power outage, gas pumps at gas stations that run on electricity generally do not operate. A church with a large solar power array, battery storage, and EV chargers could generate its own electricity to charge electric vehicles, provided there was adequate sunlight. Electric vehicles are ‘batteries on wheels’ and they can also be used for backup electricity if their batteries are sufficiently charged. A church with its own solar power, energy storage, and EV chargers could function as a resilience hub during a power outage and be able to run refrigerators and freezers to store medicines and food. These benefits are available, including the ability to save a considerable amount of money each year by not using very much local utility electricity and/or gas. Utility costs tend to rise gradually, and having a large solar array and battery storage allows the owner to avoid that increasing cost. Another benefit is moving away from a dependency mindset and taking positive action toward energy independence. Many of the church’s congregants can learn about the solar power, energy storage, and EVs at their church and may become more interested to the point they move toward their own energy independence. Solar power is clean renewable energy, but electricity provided by some local utilities comes from burning coal and/or natural gas which produces emissions which harm human health and contribute to climate change. Solar panels are much, much more affordable than they used to be and may be affordable to many people who still believe they cost too much, per MIT: “The cost of solar panels has dropped by more than 99 percent since the 1970s, enabling widespread adoption of photovoltaic systems that convert sunlight into electricity.” CleanTechnica’s Comment Policy Hello, I have been writing online for some time, and enjoy the outdoors. If you like, you can follow me on BlueSky. https://bsky.app/profile/jakersol.bsky.social Jake Richardson has 1372 posts and counting. See all posts by Jake Richardson
The Dept. of Commerce has released its preliminary antidumping duty (AD) amounts in an investigation on solar cell imports from India, Indonesia and Laos. The preliminary AD margins are 123.04% for all Indian producers, 35.17% for all Indonesian producers, and 22.46% for all Laotian producers. Combined with the preliminary countervailing duty (CVD) determinations, India has…
In 2025, solar and wind dominated global energy growth, delivering around six times more new capacity than all other power sources combined and supplying nearly all new electricity demand. With rapid expansion led by countries like Australia and several European nations, solar and wind are now the fastest-growing and central drivers of the global energy transition. Image: ISES In 2025, solar and wind provided about six times more new generation capacity (Gigawatts) than everything else combined, including coal, gas, nuclear, hydro and all other renewables. Annual electricity generation from solar and wind are approximately equal, although solar has considerably faster growth rate and is expected to pull ahead. The leading countries for combined per capita solar and wind generation are Finland, Sweden, Denmark, Australia and the Netherlands, at 3-4 Megawatt-hours (MWh) per capita per year. Australia and the Netherlands lead for per capita solar generation, while Scandinavia and Ireland lead for per capita wind generation. Typical electricity demand in advanced economies is 5-12 MWh per capita per year. This will increase to 20-30 MWh per capita per year to accommodate electrification of vehicles, industrial heating, chemical and metal production, and synthetic aviation and shipping fuels. Almost all this additional electricity will come from solar and wind. Notably rapid per capita deployment of new solar and wind in 2025 occurred in Australia, China, Chile, Finland, Netherlands and Pakistan. The latest war in the Middle East may spark rapid uptake of solar and wind in many countries, coupled with rapid electrification of land transport and heating. Growth in net nuclear generation and capacity (after accounting for retirements) was approximately zero, as has been the case for the last 30 years. There is no sign of a significant nuclear renaissance. Solar and wind each generate as much electricity as nuclear and are each also rapidly catching hydroelectricity. In 2025, new solar and wind capacity provided nearly all the additional electricity required to meet global growth in electricity demand arising from rising population, rising affluence, and electrification of transport, heating and industry. New power plant construction is now heavily focused on solar and wind, together with development of financial arrangements, skilled people and supply chains. Further growth in solar and wind capacity comes from a very large construction industry compared with the fossil and nuclear industries, which allows for much faster growth at lower cost. The top solar and wind performers are in Europe, apart from Australia. European countries share electricity across national borders, which assists with the balancing of variable solar and wind. Australia is a global solar pathfinder because it is physically isolated and low-mid-latitude (where 80% of the global population lives). By 2030, Australia is expected to reach 82% renewable electricity (mostly solar and wind). The energy transition in Australia has been straightforward. Australian solar and wind is supported by about 18 kWh per person of pumped hydro and battery storage, which is very large by global standards. Because this rechargeable storage cycles many times per year, it is equivalent to once-through storage (in the form of hydroelectricity, biomass or hydrogen) that is 30-100 times larger. Total European premium-class pumped hydro storage potential outside national parks is about 1200 Terawatt-hours, which is vastly larger than required. It will not be necessary to deploy large-scale biomass, hydrogen or CAES storage. Solar and wind provide the cheapest, lowest emissions, most reliable and most resilient energy in history. At current growth rates, combined solar, wind and hydro generation will catch combined coal and gas generation in 2030. Authors: Prof. Ricardo Rüther (UFSC), Prof. Andrew Blakers /ANU Andrew.blakers@anu.edu.au rruther@gmail.com ISES, the International Solar Energy Society is a UN-accredited membership NGO founded in 1954 working towards a world with 100% renewable energy for all, used efficiently and wisely.
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Solx’s Aurora hybrid module with Caelux’s perovskite glass aims to compete on performance beyond federal tax sunsets. Image: Caelux The agreement between two U.S. solar technology companies to produce new generation photovoltaic modules will expand the output of products using domestic-sourced components, including cells, frames and glass. The principals said the partnership between solar manufacturer Solx and perovskite glass-maker Caelux will meet U.S demand for domestic content while producing more powerful modules that will compete internationally beyond the sunset of federal tax credits. Caelux, based in Baldwin Park, California, completed the transition from research to commercial production of perovskite glass last year. The company’s Active Glass product replaces conventional solar glass as the top layer of a module, generating electricity from wavelengths that would otherwise go unused. Solx will make the hybrid versions of its Aurora module at its new factory in Aguadilla, Puerto Rico. The cells for the new line will come from Georgia-based Suniva, the largest merchant provider of U.S.- produced silicon PV cells. Origami Solar supplies its U.S.-sourced steel frames. The Aurora hybrid modules are expected to operate with an efficiency of 28%, enabling up to 30% more power density than silicon-only modules. Solx’s new factory has a stated output capacity of 1 GW of modules annually. Early-production Solx Aurora modules incorporating Caelux’s Active Glass technology are scheduled for deployment at a U.S. project by an as yet unnamed developer. Solx says commercial volumes are expected by 2027, with a target output of more than a gigawatt per year. The Solx-Caelux deal specifies 3 GW of hybrid modules over five years. The company says it has plans to open new production facilities in the mainland U.S. If supplying domestic content requirements are a factor in the partnership, John Holmes, co-founder and CEO of Solx, told pv magazine USA that short-term market signals are not the primary driver. “We’re really thinking beyond tax credit generation,” Holmes said. “We’re built to win after the sunset of tax credits. Operating with the tech edge is really a way that we differentiate ourselves and support the long-term viability of both the Caelux and Solx businesses.” According to Holmes, key factors in the partnership’s future competitiveness are the modern automation in the Aguadilla factory to manufacture modules cost-effectively, as well as the electricity production advantage enabled by Solx Aurora paired with Caelux’s perovskite glass. Scott Graybeal, CEO of Caelux, told pv magazine USA that producing perovskite glass on a large scale poses significant challenges, but the company has spent a lot of research and development effort overcoming those challenges. “There’s been a lot of good work that’s been done in research and development, a lot of great work that’s been done in the engineering of the product,” Graybeal said. “Now we’re building an organization that produces a product with 28% efficiency.” As with any hybrid technology, be they tandem PV modules or printer-scanners, the virtue of the integrated system is only as good as its major components. You don’t want a situation where the perovskite glass stops producing electricity before the silicon cells do. “The biggest challenge of producing perovskite at scale is its durability,” Graybeal said. “We’ve had a number of breakthroughs over the last 18 months that have enabled us to solve the durability problem to the point where we can support a module maker like Solx with technology that satisfies its requirements, specifically its own module warranty.” As pv magazine USAreported last year, Caelux has developed a four-terminal manufacturing process that sacrifices some conversion efficiency compared to other processes in exchange for improved durability. As an aside, Caelux was co-founded by Harry Atwater, a Caltech physics professor who as gone on to become a pioneer in space-based solar power. Holmes adds that Solx has a partner in Caelux that is a manufacturing company with a strong R&D organization, not a lab. “We’re partnering with a company that is already producing at meaningful scale,” he said. “Solx is truly a vector of giga-manufacturing capability at our Puerto Rico facility. What we are doing is integrating their mass-produced technology into our production process and optimizing it so that we can supply the market. We don’t view this as experimental in nature, or that Caelux technology is transitioning from a lab to a line. Caelux already operates a line at scale.” The Solx-Caelux deal comes at a busy time for U.S. solar technology companies. Suniva, supplier of Aurora’s silicon cells, recently announced that it is investing $350 million to build a new manufacturing plant in South Carolina expected to have an annual capacity of 4.5 GW when operational in 2027. Perovskite-silicon solar module maker Tandem PV recently opened a demonstration factory with a capacity of 40 MW in Freemont, California, that promises competition for the hybrid module market. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. More articles from Michael Puttré Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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Q4 2025 in South Australia saw grid-connected loads with spot price exposure actually being paid to use electricity about half the time (46%) – and that electricity was overwhelmingly (80%) supplied by renewables. This demonstrates a shift from managing demand to quietly needing it. Particularly in regions like South Australia, there is growing demand for demand. Peak load vs. rooftop solar capacity Image: Synapse Technology From pv magazine Australia South Australia is about to reach parity between rooftop solar capacity and peak load – a globally unprecedented scenario. Moreover, other Australian states are on a similar trajectory, hurtling Australia’s National Electricity Market (NEM) towards new international territory. Australia’s rooftop solar has more than tripled in the past seven years, growing from approximately 7 GW in 2018 to 25 GW in 2025 across all NEM states. It is the single largest electricity source in Australia by installed capacity, with the nation steadily leading the world in solar per capita. Meanwhile, peak demand in the main grid has remained relatively even, bar a modest jump in Queensland. In New South Wales (NSW) and Queensland, rooftop solar capacity now represents roughly 60–70% of peak load. In South Australia (SA), it is closer to ~90%. Of course, peak rooftop generation and peak demand occur at different times of the day, which is highly consequential for flexibility needs but more on that later. Nonetheless, at this scale, rooftop solar is no longer simply contributing energy – it is actively reshaping demand; dictating dispatch, pricing, and investment decisions; and creating ever-deeper ramp dynamics. The structural changes effected by rooftop solar are clear when we look at how demand has shifted throughout the day. Figure 2 charts the difference in intraday demand (average) between 2018 and 2025, showing a pattern of hollowed out demand during daylight followed by a steep swing into the evening peak across all mainland states. Midday demand has fallen by ~0.3 GW in South Australia and as much as 2 GW in NSW. This energy has not disappeared, it is still being consumed, but it is now generated behind-the-meter and therefore invisible to the market. This withdrawal does not smooth the demand curve but sharpens it. As the sun sets and rooftop output declines, demand returns, often within a compressed window (5pm – 8pm). Evening peaks have only increased by ~0.12 GW (SA) to 0.6 GW (Queensland) but, importantly, the ramp has grown by up to 2 GW, particularly in NSW and Queensland where the scale of both demand and rooftop penetration is largest. For context, this means that, on average, the ramp in Queensland is equivalent to turning on its largest coal generator (1.6 GW) from zero generation to full production during a five- to six-hour period, only to be turned down again as the sun rises. To offset this ramping rollercoaster and add flexibility, the Australian government introduced the popular Cheaper Home Batteries Program in 2025. The home battery subsidy enables households to store excess solar and meet part, or all, of their own evening demand. As covered in our previous analysis this policy is already reshaping grid dynamics. It may even shift the Australian grid (NEM) into a different operating regime in which the system no longer just manages peak demand, but balances midday surplus and progressively self-supplied peaks, pushing flexibility onto the demand-side. This creates space. There is now growing capacity in the system for new, sizable loads – particularly those that can align with periods of excess renewable generation or operate flexibly. In this context, parts of the NEM – especially South Australia – are increasingly well suited to support new demand-side investments. Not because demand is needed everywhere, but because at the right times, the system is starting to quietly need it. For a long time, the current demand profile and behaviour was viewed as a South Australian phenomenon – a function of its smaller system size and high rooftop uptake. But this is no longer the case. NSW, Victoria and Queensland are increasingly exhibiting the same characteristics of suppressed midday demand, sharper evening rebounds, and greater intraday volatility. South Australia, however, retains the clearest signal of where this trajectory leads. Rooftop solar alone contributes between 15% and 30% (and growing) of total quarterly generation in South Australia today, with spring and summer seasons (Q1 and Q4) unsurprisingly the highest. And as midday demand has decreased, the number of negative price intervals has increased – significantly. In fact, in Q4 2025, over-supply led to almost half (46%) of all dispatch intervals in the state returning negative prices, a NEM quarterly record. While rooftop solar is a key contributor to these negative price trends, South Australia also has the highest grid-scale renewable, predominantly wind, penetration (energy mix %) of all NEM mainland states. So much so that the same Q4 saw grid-scale renewables meet 80% of operational demand in the state. In other words, in Q4 2025 NEM-connected loads (with spot price exposure) not only got paid to use electricity about half the time, but the electricity they used was overwhelmingly supplied by renewables. Historically, the central grid challenge has been ensuring enough generation to meet peak demand. That challenge remains, but it is now accompanied by another: managing periods where there is too much generation relative to demand. This is not to imply demand itself is declining. Underlying consumption across the NEM has remained relatively stable, with some growth in regions driven by population increases and early electrification trends. What has changed is the visibility and timing of that demand to the NEM. Rooftop solar effectively removes a portion of load during daylight hours. With the rapid uptake of household batteries, it remains to be seen when – or if – that load reappears in the evenings. In short, there is a growing demand for demand itself.
This is especially so with South Australia just last week opening 11,000 km2 in Whyalla West and Gawler Ranges East to new renewable proposals as it strives towards its target of sourcing 100% net electricity from renewable generation by 2027. This further opens the field for new loads – and it is encouraging to see South Australia’s transmission planner, Electranet, preparing for such a future. It is planning for peak demand in South Australia to double over the next 15 years, with CEO Simon Emms saying it has already seen significant growth in industries including data centres, magnetite mining (a feedstock for green steel) and copper mining in the region. “If electricity is a proxy for economic growth, increased electricity consumption means we’ve got a really exciting future ahead for the state,” Emms said. Certainly, the state is making itself attractive for demand-side investment. Such an approach may become increasingly necessary for grids with high solar penetrations. Author: Lumi Adisa, Managing Partner, Synapse Technologies The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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