Solar Now

Solar power company appeals to south Alabama residents: ‘We double crop’  AL.com
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India Secured 3rd Place Worldwide in Renewable Energy Installed Capacity, Says Shri Pralhad Joshi  SolarQuarter
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Silicon Ranch addresses residents concerns for first time over proposed solar farm in Baldwin County  WKRG
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KUALA LUMPUR (April 7): Renewable energy and infrastructure company Helios Photovoltaic Sdn Bhd has submitted its prospectus for a planned initial public offering (IPO) and listing on the Frankfurt Stock Exchange in Germany, according to a statement from the company.
A company search revealed that Helios Photovoltaic, is fully owned by its 50-year-old CEO and managing director Datuk Ong Thuan Ming. Helios Photovoltaic holds a 100% interest in Helios Solar Solutions Sdn Bhd, Helios PV Homes Sdn Bhd and a 75% interest in Sasaran Padu Resources (Asia) Sdn Bhd.
According to its financial statement ended June 30, 2025 shared with The Edge, the company posted a net profit of RM24 million for the year compared with RM974,696 net loss the year before. The figures included RM10.4 million other income from debt recovery, interest, asset sales and debt waivers and a net gain on impairment of  financial assets of about RM14 million. Helios Photovoltaic has RM310,241 cash and bank balances. The company has no bank borrowings, with most liabilities consisting of amounts owed to suppliers, directors, subsidiaries, for taxes, and lease obligations.
Helios Photovoltaic said it has appointed Small & Mid Cap (SMC) Investmentbank AG as its listing bank to support the structuring and execution of the proposed IPO, which it is targeting for May 2026, subject to regulatory approvals.
Headquartered in Germany, SMC Investmentbank is an initiative of entrepreneurs, bankers, consultants and board members on the subject of “SMEs and the stock market”, according to its website.
Helios Photovoltaic held a signing ceremony with SMC Investmentbank in Kuala Lumpur on Tuesday.
According to the statement, the company, incorporated in 2010, has also launched a RM5.5 billion solar park resort project in Kelantan.
The offering will be made available to investors in Germany and other eligible jurisdictions, with proceeds intended to support the group’s long-term growth strategy, including the development and expansion of solar energy projects across Europe and Asia. The key focus markets are in Germany, Malaysia, Singapore and Cambodia.
As part of this strategy, Helios is introducing the Helios Solar Park, Wildlife Safari Conservation and Resort — a 1,000MWp solar photovoltaic facility supported by a 1,600MWh battery energy storage system.
The project will be developed across 3,000 acres in Kelantan, with targeted commercial operations between 2028 and 2029. The total estimated development value is RM5.5 billion.
Developed under Malaysia’s Corporate Renewable Energy Supply Scheme (CRESS), the project is structured as a scalable platform combining renewable energy generation with investment participation.
Helios Photovoltaic said its proprietary “Zero Net Energy Lots” concept enables corporates and investors to participate in renewable energy projects from as low as 1MWp without the need to develop, manage or operate infrastructure directly while supporting environmental, social and governance (ESG) and decarbonisation goals.

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Chinese PV company DAS Solar attended the IEA PVPS Task 12 meeting in Switzerland on April 2, 2026. The session had brought together 30 global PV sustainability researchers and industry representatives to discuss circular economy, environmental impact, policy development, recycling technologies, and life-cycle management. Maggie Fang, CSO of DAS Intelligent Environmental Technology, represented DAS Solar, which was one of only two Chinese companies present, while a China-focused project update outlined the country’s PV recycling landscape. The article said cumulative end-of-life PV modules could reach about 8 million tons by 2030 and nearly 80 million tons by 2050. DAS Solar said it is applying ‘Design for Recycling’ principles through wafer thinning and reduced silver consumption, and has developed a fully physical recycling process. Backed by over 50 patents related to PV recycling, DAS Solar said its validation tests recorded an overall recovery rate of 95.92%.

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Solar photovoltaic energy has become the cheapest source in the world and is growing at a rapid pace, displacing coal, gas, and nuclear energy.
The price drop has been decisive:
In comparison:
The Sun irradiates more energy in one hour than humanity consumes in a year. With solar panels on less than 1% of the Earth’s surface, the entire world’s energy demand could be covered.
One of the major challenges of solar energy is its intermittency: it only produces electricity when there is sunlight. However, advances in lithium batteries, thermal storage, and hybrid systems are allowing solar energy to become a reliable and continuous source. Storage adds between 2 and 3 cents per kWh but ensures stable supply even during nighttime or cloudy days.
Additionally, integration with smart grids and the development of bifacial panels (which capture energy on both sides) increase efficiency and reduce costs.
Solar energy is emerging as the main global energy source. Researchers from the Lappeenranta University of Technology estimate it could cover up to 76% of global electricity in the future. Its exponential growth, reduced costs, and ability to displace polluting sources make it the cornerstone of the energy transition towards a sustainable model.
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Solar PV drives all Tunisia renewable capacity growth in 2025  Utilities Middle East
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CHICAGO — Marist High School has completed a major on-campus solar energy installation, marking a significant milestone in the school’s ongoing commitment to sustainability, environmental stewardship and responsible leadership. The fully installed and operational solar photovoltaic system is located on Marist’s campus at 4200 W. 115th Street in Chicago.
Developed in partnership with Mission Energy and constructed by 93Energy, the project represents a long-term investment in clean, renewable energy and operational efficiency. The system is now actively generating power for the campus, delivering both environmental and financial benefits.
Over 900 solar modules with a total system capacity of approximately 579 kW DC were installed on the 62-year-old building’s roof. The completed solar is expected to generate an estimated 695 kilowatt-hours of electricity and is expected to save $80,000 to $90,000 in annual energy costs annuallyl.
In addition to reducing energy costs, the system is expected to offset approximately 490 metric tons of carbon dioxide each year, an environmental impact equivalent to removing more than 100 gasoline-powered vehicles from the road annually.
“This project reflects Marist High School’s commitment to being thoughtful stewards of our resources and leaders within our community,” David Waterman, director of buildings and grounds for Marist. “The completion of this solar installation allows us to reduce our environmental footprint while providing real-world learning opportunities for our students.”
Beyond its operational impact, the solar installation offers meaningful educational and community value. As a fully functioning system, it serves as a real-world example of renewable energy in action, offering hands-on learning opportunities for students, staff, and visitors while reinforcing sustainability goals across the campus.
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Researchers at the University of New South Wales (UNSW) have developed the world’s first comprehensive map of ultraviolet (UV) radiation for solar modules.
UNSW said that the research reveals that current industry testing standards may be dramatically underestimating real-world UV exposure and potentially shortening the lifespan of next-generation solar technologies by up to a decade.
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The high-precision model, led by Dr Shukla Poddar and supervised by Professor Bram Hoex and Associate Professor Merlinde Kay, with contributions from Dr Phillip Hamer and Mr Shuo Liu, calculates how much UV radiation solar modules receive across different parts of the world depending on climate, atmospheric conditions and mounting configuration.
Published in the IEEE Journal of Photovoltaics, the work provides the first global-scale comparison of UV exposure for fixed-tilt and sun-tracking solar systems, offering the industry a new way to predict long-term performance and durability that accounts for location-specific environmental factors.
Until now, there has been no comprehensive method for estimating the amount of UV radiation a solar panel receives at a given location, particularly when modules are tilted or mounted on tracking systems.
Most global UV data is measured on horizontal surfaces, which does not reflect how modules are actually installed in the field. The UNSW modelling approach addresses this gap by incorporating local atmospheric inputs such as clouds, water vapour and aerosols, allowing developers to tailor assessments to specific sites.
The model was validated using high-precision UV-measuring instruments in Europe and compared with long-term climate datasets spanning 2004 to 2024.
“We’ve basically developed a method to quantify the amount of ultraviolet radiation based on different spectral wavelengths, and we’ve produced a global map that shows what you could expect depending on your location,” corresponding author Dr Poddar said.
“It gives a holistic overview for manufacturers or developers who want to install panels somewhere, without having to do all the background calculations themselves.”
The findings carry particular significance as the solar industry rapidly deploys advanced high-efficiency technologies designed to capture a broader portion of the solar spectrum, including ultraviolet light.
While traditional silicon solar modules primarily rely on visible and infrared light to generate electricity, newer cell architectures such as TOPCon and heterojunction are engineered to harness UV radiation for improved conversion efficiency.
That improvement, however, may come with unintended consequences for long-term reliability, with recent research documenting notable UV sensitivity in certain next-generation designs.
“Our results highlight that modules with similar technology and orientation can still exhibit region-specific degradation,” the researchers state in the paper.
“This is due to the influence of local weather and climate when exposed to outdoor conditions. This underscores the need for climate-specific indoor testing and accelerated tests for reliability and better lifetime predictions.
“Notably, UV photodegradation alone can account for nearly a quarter of the total annual degradation in monocrystalline silicon modules in regions with high UV dose, potentially reducing system lifetime by seven to ten years.”
Perhaps one of the study’s most significant findings concerns solar modules mounted on tracking systems, which move throughout the day to follow the sun’s path and maximise energy capture.
The research demonstrates that these installations are exposed to substantially more UV radiation than fixed-tilt systems, creating accelerated degradation pathways that current testing standards fail to capture adequately.
“For single-axis or double-axis trackers, it’s worse,” Dr Poddar said.
“They’re always trying to track the sun to catch the maximum amount of sunlight. That means they’re also getting the maximum UV on top of them, which makes those panels more susceptible and vulnerable.”
In high-irradiance regions, the research indicates that UV-related degradation for single-axis tracking systems could reach around 0.35 per cent per year from UV exposure alone, a figure that accumulates significantly over typical project lifespans.
Manufacturers typically quote overall degradation rates of around 0.5 per cent per year, often assuming a steady, linear decline in performance.
However, the UNSW study suggests that degradation may not follow a strictly linear pattern and that UV exposure could account for a significant fraction of total performance loss, particularly in high-irradiance environments where atmospheric conditions concentrate ultraviolet radiation on panel surfaces.
“That number might not sound dramatic at first,” Dr Poddar said. “But when you quantify it over 20 years, it accumulates quite quickly.”
The implications extend directly to project economics and warranty structures, particularly as previous UNSW research has shown that up to one-fifth of solar PV modules degrade 1.5 times faster than average.
The team’s global UV mapping provides a mechanism to identify which geographic regions and mounting configurations face the highest risk of accelerated degradation, enabling more accurate financial modelling and warranty risk assessment before deployment.
Current international standards require solar modules to pass a UV test equivalent to 15 kilowatt-hours per square metre before receiving certification for deployment. This reaffirms some of the key messages UNSW scientists recently told PV Tech Premium regarding UV testing protocols for TOPCon cells.
The UNSW research reveals a disconnect between this testing threshold and actual field conditions, particularly in high-irradiance regions where modules may receive that cumulative UV dose in little more than a month of operation.
In Alice Springs, Australia, for example, modules experience the entire standard UV test dose within approximately 30 to 40 days of outdoor exposure.
“It is a significant underestimation of the amount of UV radiation the panels may be exposed to,” Dr Poddar said.
“So a module can pass the UV test, but in reality, it could perform much worse because we don’t have sufficiently stringent tests.”
The findings are particularly relevant as modern high-efficiency technologies become more widespread, with industry reports documenting UV sensitivity in certain designs that may not be adequately screened by existing certification protocols.
The challenge is compounded by the fundamental physics of advanced solar cell technologies, which become increasingly vulnerable to degradation as they approach theoretical performance limits. 
UNSW research has previously revealed atomic-scale self-repair mechanisms in silicon solar cells that can partially offset UV-induced damage, but these mechanisms may be insufficient to counteract the elevated UV doses delivered by tracking systems and high-irradiance locations to next-generation cell architectures over multi-decade operational periods.
“One of the key messages from our paper is that the UV testing standards need to be amplified or changed,” Dr Poddar added.
“With new high-efficiency PV technologies being rolled out so quickly, we need to ensure the standards reflect real-world conditions.”
The researchers emphasise that the new modelling tool is designed to help manufacturers, developers and asset owners make better-informed decisions throughout the project lifecycle.
UNSW believes that, before installation, developers could use the global UV map data to conduct more rigorous accelerated UV stress testing on candidate modules, selecting products that demonstrate resilience to the specific UV exposure profile of the deployment location and mounting configuration they intend to use.

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Ed Miliband overrules locals to approve Britain’s biggest solar farm  Yahoo
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Heelstone Renewable Energy, Part Of Qualitas Energy, Secures Funding And Starts Building Two U.S. Solar PV Projects For Hyperscale Data Center Client  SolarQuarter
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BarcelonaThe Catalan energy company Estabanell has signed a syndicated loan of 22 million euros with Triodos Bank and the Institut Català de Finances (ICF) to deploy 16 of its own photovoltaic solar parks. In a statement, the Catalan company, based in Granollers (Vallès Oriental), explained that Triodos will contribute 15 million and the ICF the remaining seven million.
With this financing, structured through a project finance, Estabanell aims to increase its photovoltaic capacity by 62.8 MWp installed, mainly with solar parks in Catalonia. “This agreement represents a significant boost for the group’s growth strategy, as it allows us to advance in the construction of photovoltaic parks under the distributed generation model that Estabanell is committed to,” the company stated.
These new renewable generation facilities –most of which will be developed with the group’s engineering subsidiary specialized in photovoltaic generation, Estabanell Innover– are expected to be operational before June 30, 2027.
Estabanell is currently finalizing the construction and connection of three solar parks in Vidreres (Selva), La Garriga (Vallès Oriental), and Figuerola del Camp (Alt Camp), which are part of the same strategic axis of growth in renewable generation.
Among the solar parks that will come into operation during 2027 are those in Fonollosa (Bages), El Catllar (Tarragonès), Manlleu (Osona), and Moià (Moianès), as well as other facilities outside Catalonia that are part of the group’s global renewable development plan.
The general director of Estabanell, Teresa Roig, highlights: “This financing agreement marks a turning point in our capacity to generate our own renewable energy and allows us to move towards a more sustainable energy model, rooted in the territory and aimed at ensuring a clean and competitive supply for our clients.” “The confidence of Triodos Bank and the ICF strengthens the solidity of our model and the rigor with which we approach each project,” says Roig.
In the words of Miguel Ángel Amores, head of renewable energies and environmental technologies at Triodos Bank, “this financing reflects how banking can continue to support the energy transition and reduce dependence on fossil fuels with solid structures that combine diversification, stable income through long-term PPAs, and the full support of a company with a great energy track record like Estabanell”. “This project is a great example of support for the real and local economy, where the savings of our clients, many of them Catalan, are transformed into renewable generation plants in Catalonia with good environmental integration, promoted by a Catalan energy company with a strong local presence and with the additional financial support of the Institut Català de Finances,” states Amores.
The CEO of ICF, Vanessa Servera, affirms that “sustainability is one of the strategic financing pillars of the public promotion bank and ambitious projects like Estabanell’s contribute to fostering the energy transition of companies and society as a whole and drive a more sustainable future”.

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India’s installed solar power capacity has crossed the 150 GW mark, numbers put out by the Ministry of New and Renewable Energy show. This happened as the installations in March reached a record 6.65 GW. 
In the full year 2025-26, India’s solar India’s solar installations were 44.61 GW, taking the cumulative capacity to 150.26 GW. 
Alongside, there has been another notable record—in wind power. India installed a record 6.05 GW of wind power capacity, the highest ever, surpassing 2016-17 record of 5.2 GW. 
Yet another record achieved in 2025-26 is the total renewable energy capacity installations crossing the 50 GW mark. Total installations during the year were 50.9 GW. 
With this, India’s total renewable energy installed capacity, excluding large hydro, stands at 223.27 GW. Including large hydro (51.41 GW), the number is 283.46 GW. 
Also noteworthy is the point that within solar, rooftop installations crossed the 25 GW mark—they now stand at 25.73 GW. 
The Union Minister for New and Renewable Energy and Consumer Affairs, Food and Public Distribution, Mr Pralhad Joshi said today India ranks third globally in Renewable Energy Installed Capacity. 
“Distributed Renewable Energy (DRE) from Solar has emerged as a significant component of this growth, contributing 16.3 GW (36%) out of the 44.61 GW installed during 2025–26,” says a MNRE press release. This includes 7.6 GW under PM KUSUM and 8.7 GW from rooftop solar. 
Alongside, non-fossil capacity addition in 2025-26 is 55.29 GW and this is the highest increase in any year. Previously the highest increase was 29.5 GW during 2024-25, the release said. 
Published on April 8, 2026
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With a Secretary of State decision now in place granting the Springwell Solar Farm Development Consent Order, the District Council is keen to further explore with operators EDF how a commitment to provide community benefits of £400 per megawatt of installed capacity will be spent on local projects, and to align with the Council’s adopted Large Scale Solar Energy Community Benefit Policy.
The proposal to install 800MW of generating capacity located at the A15 between Lincoln and Sleaford was considered to be a Nationally Significant Infrastructure Project (NSIP) which meant it needed to be determined by the Secretary of State, who has now published his decision.
North Kesteven District Council’s position was to comment on the scheme and its local impact and to raise objections on a number of grounds. In doing so it highlighted the need for there to be a high regard for the community and the impacts on landscape and visual amenity, grid connection arrangements, cultural heritage and archaeology, ecology and biodiversity net gain, battery storage and associated operational safety and ongoing agricultural use.  
These concerns were framed within a broader context of overall high level policy support, given the scope of the area’s Central Lincolnshire Local Plan and its commitment to supporting a transition to a net-zero carbon future through appropriately-located renewable energy generation.
Council Leader Cllr Richard Wright said that this scheme seeks to provide renewable energy to power 180,000 homes over an intended lifespan of 40 years. Whilst the Council has clear ambitions and actions with regards to the changing climate and clean energy provision, our position has always been one of the right schemes in the right place of the right size. In this case, this led to objections being raised.
He said: “Those objections we did raise were mainly in respect of how the scheme impacted on best and most versatile agricultural land, with very nearly half of it taking up land of this classification.
“We would still ask that through careful location of the panels and onsite infrastructure this is kept to a minimum and also to consider battery technologies that have lowest environmental impact and are demonstrably the safest.
“We are also pleased that the Secretary of State has listened and responded to our concerns regarding the timings of works in relation to the proposed new substation at Navenby, and that we have secured significant financial contributions of over £2m towards delivering a skills and education package and biodiversity gains over the 40-year lifetime of development.
“We welcome this final decision on what has already been a long-running project and will now look forward to EDF fulfilling their commitment in relation to community benefits in line with our adopted policy.”
For the latest news on North Kesteven District Council visit our council news pages
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Nature Communications volume 17, Article number: 3037 (2026) Cite this article
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The rapid growth of tropical cities and the rising challenges of climate change call for efficient, low-carbon energy systems. Solar photovoltaics could play a key role, but deployment in tropical climates is constrained by localized thunderstorms that cause rapid generation fluctuations and stress electricity grids. While electric vehicles could balance such fluctuations by acting as distributed energy storage, this potential has not been systematically explored. Here, using Singapore as a case study, we develop a decentralized, district-level vehicle charging strategy that aligns with urban mobility patterns inferred from mobile phone data. Contrary to conventional centralized charging strategies, our approach substantially reduces grid flows, enabling greater photovoltaic integration into the existing grid infrastructure. We further show that detailed urban mobility patterns are critical to the balancing performance of electric vehicle storage. Our results highlight the potential of coordinated photovoltaic and electric vehicle systems for large-scale solar energy deployment in tropical cities.
Urban growth is increasingly concentrated in tropical regions where  ≈  50% of the world’s population is expected to live by 2050¹. This trend, particularly evident in ever-expanding megacities such as Lagos, São Paulo, or Jakarta, is associated with rapidly rising energy demands and a pressing need for low-carbon energy infrastructures that limit the impact on global warming².
Solar photovoltaic (PV) is currently becoming one of the key renewable energy technologies to meet the global growth of electricity demand while reducing carbon emissions^3,4,5,6. Indeed, PV installations have experienced rapid global expansion, driven by declining costs and supportive policies⁷. However, due to the intermittent nature of solar energy, the large-scale integration of PV installations poses several operational challenges to the electricity system^8,9. A prominent example is the so-called ‘duck curve’, where the net electricity demand (total demand minus PV output) across a region dips when PV injections become high at noon (‘duck’s belly’), and then suddenly rises when the sun sets in the early evening while people still need high amounts of electricity (‘duck’s neck’). As a result, electricity system operators face an oversupply of generation during the valley hours and steep demand increases in the early evening that may require PV curtailments¹⁰ and large amounts of highly flexible generators like gas turbines¹¹. While the duck curve problem has so far been observed typically in more dry climates like California in the USA¹² and Shandong in China¹³, its challenges intensify in tropical climates where localized thunderstorms and rapidly changing cloud covers additionally introduce highly fluctuating PV injections that vary strongly across small geographic areas^14,15 (Supplementary Note 1). Such periods of strong local imbalances between electricity supply and demand may jeopardize the security of the electricity supply if there are insufficient electricity grid capacities to balance out these fluctuations across larger regions^16,17,18. Therefore, addressing the intermittent availability of solar energy is essential to enabling the deployment of large-scale PV energy in tropical cities.
Controlled charging of the growing number of electric vehicles (EVs)^19,20,21 may offer a scalable and cost-efficient solution to these challenges^22,23,24,25. For instance, at the city-wide aggregated power system level, previous work has shown that incentivizing vehicle charging during the daytime, when PV generation is high, flattens the duck curve, which reduces the need for PV curtailments or capital investments in flexible generators, stationary energy battery storage or other technologies that would otherwise be required to balance out the intermittent generation^26,27,28. The balancing effects are further amplified if EVs can feed the energy stored in their batteries back to the electricity grid. This bidirectional energy exchange through vehicle charging and discharging is known as vehicle-to-grid (V2G) and effectively turns EVs into large amounts of decentralized, mobile energy storage devices²⁹.
These well-studied dynamics at the aggregate power systems level^{23,26,27,28,30,31} suggest that controlled EV charging can also help balance out the more local and more short-term PV generation fluctuations present in tropical regions. This may not only flatten the net electricity demand curve at the system level but also reduce the need for costly grid expansions by minimizing the flows resulting from strong spatial and temporal imbalances in PV generation. However, despite the growing importance of tropical cities, this potential has not been explored systematically, possibly due to the lack of detailed individual mobility data needed to assess the spatial and temporal availability of EVs for charging and discharging.
Here, we address this gap by integrating fine-grained EV mobility patterns derived from mobile phone data and PV generation patterns derived from solar irradiance data into an electricity grid model. Using Singapore as a case study of a tropical city and applying different future EV and PV integration scenarios, our framework enables us to assess EV charging strategies for their ability to support large-scale PV integration by balancing highly intermittent PV generation in tropical climates. Our analysis reveals that the commonly assumed EV charging optimization at the system level flattens the city-wide duck curve and reduces the associated peak net demand, but – counterintuitively – induces even larger flows on the electricity grid. In contrast, controlled EV charging optimized to smooth fluctuations at the more local urban district level not only flattens the city-wide duck curve but also reduces grid flows, thereby lowering the need for infrastructure upgrades. In addition, we demonstrate the importance of considering detailed urban mobility patterns in evaluating the EV potential by comparing the effectiveness of controlled EV charging on weekdays and weekends.
In Singapore, a tropical city-state with ≈ 5.9 million inhabitants, solar energy is considered the only viable option for large-scale renewable energy use due to limited resources otherwise³². To assume realistic future high-PV-high-EV scenarios, we follow the projections of Singapore’s ‘PV Roadmap’³³ and ‘Green Plan’³⁴, according to which the maximum installed PV capacity reaches 8.6 gigawatt-peak (GW_p) and all cars (N ≈ 0.7 ⋅ 10⁶) are assumed to be electric by the year 2050. PV panels are thereby installed on all usable surfaces, including roofs and façades of buildings, infrastructures, and suitable water bodies. For the same year, the city’s peak base electricity demand (i.e., without EVs and PV) is estimated to be 11.5 GW (see Methods). Note that the number of cars per resident is low (≈ 0.12), even when compared to other ‘car-lite’, high-density cities (e.g., ≈ 0.23 in New York City).
Based on these values for 2050, we consider five different scenarios to quantify the benefits of controlled EV charging for the integration of PV: i) “No PV, no EV” – neither PV nor EVs are integrated, ii) “PV only” – PV is integrated but without any EV adoption, iii) “PV+uncontrolled charging” – both PV and EVs are integrated and EVs simply charge until their batteries are full when they are parked, iv) “V2G only” – no PV is integrated but EVs are adopted and obey controlled bidirectional charging where both charging and discharging behaviors are optimized, v) “PV+V2G” – both PV and EVs are integrated and EVs obey controlled bidirectional charging.
We simulate the spatial and temporal variation of the PV generation by combining solar irradiance data with fine-grained building geometry information (Methods). In addition, the detailed mobility patterns of EVs are needed to determine the periods and locations when they are parked and, therefore, available for charging and discharging³⁵. To that end, we simulate the EV mobility using mobile phone data and the TimeGeo model described in refs. ^31,36 (Supplementary Notes 2 and 3). This framework generates detailed daily trajectories (i.e., time-stamped sequences of visits to different locations) for each individual of an entire population by enriching sparse location data from mobile phones with a probabilistic human mobility model. Having established these general mobility patterns, we then use transportation mode data to extract the trips that are made by EVs (Supplementary Note 3) and to determine charging and discharging patterns. A series of validation studies using independent ground-truth datasets, including census data and carpark occupancy records, confirm that the mobile phone data are sufficiently representative across Singapore and that our EV mobility estimates are consistent with empirical observations (details in Supplementary Note 3). Finally, to study the combined impact of PV and EV integration on the power flows across the city-wide electricity grid, we make use of an existing electricity network model for Singapore³⁷ (Supplementary Note 5). Possible future changes in the network topology are thereby not considered.
We start assessing the impact of thunderstorms by examining the dynamic grid loadings with PV integration (“PV only” scenario). Figure 1a depicts the solar irradiance at 10:30 am, 12:00 pm, and 1:30 pm of a typical day with thunderstorms. Solar irradiance shows significant variations over short spatial and temporal scales due to thunderstorms. For instance, differences of up to 1000 W/m² can be observed between the east and west part of the city ( ≈  55 km distance), and local fluctuations of 800 W/m² within the short period between 10:30 am and 12:00 pm. Lower irradiance during thunderstorms leads to rapid decreases in the PV generation and therefore to sharp local peaks in the net electricity demands (Supplementary Note 6). This results in dramatically increasing grid flows that balance out these demand differences. Indeed, as can be observed by comparing Fig. 1a with Fig. 1b, districts with lower solar irradiance tend to exhibit higher line loads, and vice versa. Figure 1c additionally illustrates the detailed load profile of an exemplary line during the same day, with periods affected by thunderstorms highlighted. During the two thunderstorm periods, the line load shows sharp peaks, followed by rapid drops as the thunderstorms pass.
a Solar irradiance on a typical day with thunderstorms (April 20, 2024). The white lines are urban district borders. b Resulting loads of the lines expressed as the fraction of their maximum load on that day (load factor) in the “PV only” scenario. c Detailed temporal load variations on the exemplary line 74 (depicted in b), measured as the difference between the “PV only” scenario and the baseline load of the “No PV, no EV” scenario. To highlight the impact of thunderstorms, we also plot load variation on the same day, assuming no cloud coverage. d Thunderstorm-induced load increases of all lines during a simulated 2-month period of the “PV+uncontrolled charging” scenario. For each line, the maximum load over all days with thunderstorms, versus the maximum load over all days with no cloud coverage, is plotted. For the majority of lines, the maximum load is substantially higher during days with thunderstorms (lines with a maximum load larger than 1000 MW (7 out of 85) show no effect and are omitted for visualization purposes). PV stands for photovoltaic, and EV stands for electric vehicle.
As shown in Fig. 1d for all lines and an extended period of 2 months (using solar irradiance data from March 20th to May 20, 2024), these significant increases in the line loads due to thunderstorms persist after integrating EVs without a controlled charging scheme (“PV+uncontrolled charging”, see Methods). On several lines, maximum loads increase by more than 100% on days with thunderstorms (characterized by strong irradiance fluctuations) compared with cloud-free, high-irradiance days. This shows that even conservative security margins of 33-50% can be insufficient if line flow limits do not account for thunderstorms (a 100% load increase corresponds to a required security margin of 50%). Such increases in peak line loads therefore put high pressure on the transmission lines and, without energy storage, may require costly upgrades to the grid infrastructure.
Having established the impact of thunderstorms, we now examine the potential of controlled EV charging for mitigating these additional burdens on the electricity grid (“PV+V2G” scenario). We start with a conventional ‘system-level’ V2G optimization approach which seeks to minimize the aggregated, city-wide peak net demand and is typically used to assess the benefits of V2G for the power generation level^27,28 (Methods). Figure 2a shows the effect of this controlled EV charging scheme on the flow dynamics of an exemplary line (same as in Fig. 1c) over the course of a day. Interestingly, optimizing EV charging at the system level leads to a strong peak in the flow magnitude that is not only higher than in the “PV only” scenario but even exceeds the maximum flow observed in the “PV+uncontrolled charging” scenario. This observation may appear counterintuitive, as V2G, unlike uncontrolled charging, enables vehicles to feed power back to the grid, reducing net electricity demand and, consequently, line flows. However, the system-level “PV+V2G” strategy prioritizes minimizing peak net demand at the city-wide scale, which permits localized demand fluctuations. These local variations, in turn, lead to significant line flow variability.
To tackle this challenge, we apply a decentralized, ‘district-level’ V2G optimization scheme (Methods). It minimizes the peak net electricity demands of each urban district and thus can be expected to alleviate the observed thunderstorm-induced grid flows. Singapore comprises 55 urban districts (‘planning areas’) with areas ranging from ≈1 km² in the dense downtown to ≈20 km² in the surroundings. Indeed, district-level “PV+V2G” is able to reduce the peak load on the exemplary line compared to both the “PV only” scenario and the “PV+uncontrolled charging” scenario (Fig. 2b). This reflects its focus on flattening the demand curves at the more local level, which reduces the need for electricity exchanges across districts and thus naturally lowers the line flows. Note that these peaks are, however, still higher than in the scenarios without PV (“No PV, no EV” and “V2G only”).
a, b Flows on the same exemplary line as in Fig. 2c for the same day with thunderstorms when optimizing EV charging at the system level (a) and at the district level (b), compared to all other PV and EV integration scenarios (here the flows are shown in absolute values). c–f Effectiveness of EV charging optimization. For all sunny days (c, d) and all thunderstorm days (e, f) of the 2-month period, the maximum load of each line after system-level (c,e) and district-level (d, f) optimization is plotted against the corresponding value in the “PV+uncontrolled charging” scenario. The continuous lines are linear fits to the data. A simulated weekday is taken for the daily mobility patterns. For enhanced visualization, lines with maximum flows of more than 1000 MW (7 out of 85) are shown separately in Supplementary Fig. S14. EV stands for electric vehicle, PV stands for photovoltaic, and V2G stands for vehicle-to-grid.
Extending the analysis to all lines and to the 2-month period of solar irradiance data generalizes these observations (Fig. 2c-f). On sunny days without thunderstorms, both system-level (Fig. 2c) and district-level (Fig. 2d) charging optimization are able to reduce the maximum line loads compared to the “PV+uncontrolled charging” scenario, whereas the district-level optimization shows larger gains. This superiority of the district-level optimization on days without thunderstorms suggests that this approach is also beneficial for dry climates. On days with thunderstorms, however, system-level optimization increases the maximum loads on the majority of the lines (Fig. 2e): Counterintuitively, system-level charging optimization – a common approach when evaluating V2G effectiveness – exacerbates grid loading in tropical climates. District-level EV charging optimization, in contrast, is able to substantially reduce the loads compared to the combination of PV with uncontrolled EV charging (Fig. 2f), yielding reductions of 18.1  ± 11.8% (mean  ± standard deviation). This confirms that decentralized EV charging optimization, balancing out demand fluctuations at the district level, effectively reduces the burden on the grid due to PV integration in tropical climates. More detailed statistics across all PV and EV integration scenarios are given in Supplementary Note 8. An extensive sensitivity study shows that district-level V2G optimization remains effective across a wide range of different operating conditions, including varying battery capacities, (dis)charging rates, EV adoption levels, and PV integration scenarios (Supplementary Note 9). Moreover, a detailed alternating-current (AC) power flow analysis shows that network voltage levels remain within acceptable limits (Supplementary Note 10). Generally, we find qualitatively similar, but less strong, effects when using uni- instead of bidirectional EV charging, i.e., not allowing EVs to feed energy back to the grid (Supplementary Note 11).
Is district-level “PV+V2G” also able to reduce the original duck-curve problem at the aggregate, city-wide level? Indeed, as shown in Fig. 3, the large-scale deployment of PV (“PV only”) induces a strong dip in the city-wide net demand in the early afternoon, especially on sunny days (for days with thunderstorms see Supplementary Note 6). System-level “PV+V2G” almost completely flattens this duck curve (Fig. 3a). District-level “PV+V2G” is able to reduce the peak to a similar degree, while some dip in the demand curve persists (Fig. 3b). However, the demand increase in the late afternoon is substantially less steep compared to the “PV only” scenario and comparable to the usual base demand increase (“No PV, no EV” scenario) in the morning hours. Thus, district-level EV charging also significantly reduces the original duck-curve problem, albeit to a slightly lesser extent than the system-level approach. Note that controlled charging without PV (“V2G only”) flattens the curve (Fig. 3), but there is no appreciable reduction in the peak demand compared to the base scenario (“No PV, no EV”). Similarly, integrating PV alone (“PV only”) has no effect on the peak demand when only PV is integrated. In other words, only the combined deployment of PV and EVs can effectively lower peak demand and reduce dependence on non-PV generators.
a City-wide net demand profile with system-level EV charging optimization for a typical day without thunderstorms (solar irradiance data from March 22, 2024). b Corresponding city-wide demand with district-level EV charging optimization on the same day. The arrows depict the effect of V2G on peak net demand reduction relative to scenarios with PV combined with uncontrolled EV charging. The achieved peak reduction of the system-level optimization is similar to the district-level optimization. EV stands for electric vehicle, V2G stands for vehicle-to-grid and PV stands for photovoltaic.
Since EVs can only charge or discharge while parked, their spatio-temporal energy storage potential is strongly determined by their detailed mobility patterns. This is particularly evident during thunderstorms, when solar irradiance drops and recovers rapidly, leading to sudden reductions and increases in PV generation. These generation losses can be compensated through V2G support from EVs, but only if a sufficient number of EV batteries are available – this availability depends on the number of parked EVs connected to the grid.
To explore the importance of this factor, we compare the effectiveness of controlled EV charging on weekdays with weekends. Figure 4a, b illustrates the average number of parked EVs simulated over a month, broken down into weekdays and weekends, in a typical peripheral residential district and a typical central commercial district, respectively. The residential area exhibits an inverted bell curve in EV availability, with most vehicles departing in the morning and returning in the evening, limiting the potential for daytime charging and energy storage. On the weekend, this curve is substantially flatter with many more cars parked during the daytime, which increases the potential of V2G to smooth out local drops in the PV outputs due to thunderstorms. This trend is primarily due to the absence of work obligations for many residents on weekends, reducing the need to commute.
Conversely, the commercial district with its offices and shopping malls shows the opposite behavior with a high EV availability during the daytime and low availability during the night. This pattern aligns with business hours, as many vehicles remain parked at workplaces and commercial places, creating an opportunity to synchronize EV charging with solar PV generation effectively. Furthermore, and again being in contrast to the residential area, the commercial area has a lower number of cars parked during the weekend compared to the weekdays, which reduces the potential of V2G to smooth out local drops in the PV outputs due to thunderstorms. This can again be explained by the absence of work commutes during the weekends.
Based on this observation that EVs tend to be more evenly distributed across the city during weekends, we hypothesize that controlled EV charging reduces grid loadings more effectively on the weekends compared to weekdays. This expectation is confirmed in Fig. 4c and Supplementary Fig. 25, showing the results from the district-level “PV+V2G” strategy. The maximum line loads are appreciably reduced during weekends compared to weekdays, highlighting the importance of considering individual EV mobility patterns for evaluating their impact on the power grid performance. Note that the base electricity demands (i.e., the district-level demands without EVs) are assumed to be the same on weekdays and weekends (Methods), so that these differences are a direct causal result of the mobility patterns.
a, b Number of parked EVs in a residential district (a) and in a commercial district (b) during weekdays and weekends, averaged over a simulated period of one month. c Comparison of maximum line loads between weekdays and weekends in the “PV+V2G” scenario with district-level optimization over the one-month period. For the daily solar irradiance, a typical day with thunderstorms is taken (April 20, 2024, same as in Fig. 1a). EV stands for electric vehicle, PV stands for photovoltaic and V2G stands for vehicle-to-grid.
In this work, we have examined the potential of EVs to support the large-scale PV deployment in tropical cities by combining detailed mobility patterns and EV charging optimization with fine-grained PV output data and electricity grid simulations. Using Singapore as a case study, our key insights are as follows. First, rapidly passing thunderstorms, characteristic of tropical climate zones, lead to highly localized drops in PV output, resulting in strong net demand fluctuations and grid overloads. Second, contrary to expectations, controlled bidirectional EV charging aimed at balancing out demand fluctuations at the city-wide level exacerbates line loadings. Third, to overcome this challenge, we have introduced a district-level EV charging scheme that smooths the net demand fluctuations of each urban district and is able to significantly reduce the burden on the electricity grid. Fourth, we have shown that the detailed mobility patterns have a significant impact on the effectiveness of controlled bidirectional EV charging with respect to supporting the integration of PV in tropical climates. In particular, we observe that in some residential areas, EV charging may be insufficient to flatten net demand on weekdays due to limited availability of EVs during the daytime, so additional stationary energy storage systems may be needed to maximize PV use.
Electricity network reinforcements require substantial capital investments and lengthy planning processes, especially in dense urban areas³⁸. The introduced district-level V2G scheme mitigates both the duck curve problem and this infrastructure challenge. Drawing on the literature on the economics of electricity network planning, we estimate for Singapore potential savings of several hundred million up to several billion SGD (see Supplementary Note 13). These main benefits of the proposed V2G scheme must be considered in relation to the associated costs. For EV users, these costs are primarily due to accelerated EV battery degradation and investment in bidirectional chargers³⁹. Using a detailed battery degradation simulation and an economic analysis (details in Supplementary Note 14), we estimate that the required compensation cost to break even with battery degradation and charger costs is SGD 11.20-24.16 per MWh of V2G energy flow. These values are comparable to those previously reported for low-usage V2G schemes and in the range of incentive payments from current demand-side flexibility programs. The district-level V2G scheme also requires communication and control infrastructure. Although detailed cost estimates are currently difficult to quantify⁴⁰, these components are similarly essential in other V2G systems⁴¹, and we therefore expect their costs to be within a comparable range. Several large-scale V2G pilot projects worldwide have already demonstrated the practical feasibility of implementing the required communication and control systems (Supplementary Note 1).
Our framework can support progress towards policy-driven sustainability and energy security goals. In Singapore, for instance, it may directly contribute to achieving the national net-zero emissions target for 2050⁴² by accelerating the large-scale integration of PV (through deferring costly grid reinforcements) and by enhancing the attractiveness of EVs (e.g., by enabling new revenue streams through controlled charging). Indeed, a recent system dynamics model estimates that net carbon emission savings can reach up to 29.1 million tonnes by 2040, assuming a supportive policy scenario that enables the PV capacity to reach  ≈  8% of the total electricity generation by the same year³². Existing policy recommendations towards this goal could be extended to align more closely with our approach. For example, while Singapore’s national ‘Green Plan 2030’^32,34 outlines specific interim milestones towards the net-zero target, including a full transition to cleaner-energy vehicles by 2040, our results suggest the additional design of complementary incentive programs, such as attractive compensation schemes for EV users participating in controlled charging. A more detailed discussion of the alignment of our work with Singapore’s Green Plan 2030 and beyond is given in Supplementary Note 15.
Overall, our study highlights that in Singapore, a region with low vehicle ownership, an appropriate EV charging strategy can significantly support large-scale PV deployment. Consequently, we expect that the revealed benefits of the district-level EV charging also apply to other urban regions with similar or higher EV adoption rates, as our sensitivity analysis shows that higher EV shares are associated with stronger line load reductions (Supplementary Note 9). At the same time, a higher number of EVs distributes V2G participation across more vehicles, reducing the average battery degradation per vehicle. Urban structures that differ from the compact spatial organization of Singapore may imply changes in the detailed energy consumption and mobility patterns⁴³. We expect that such changes may have ‘second-order’ effects on the grid load mitigation potential, comparable to the effect of different mobility patterns during weekends and weekdays (Fig. 4), which should be evaluated on a case-by-case basis. Furthermore, we have shown that our decentralized load-balancing framework can also be beneficial for reducing grid loads in non-tropical settings.
Our work has several limitations that open promising avenues for future research. First, by focusing on urban districts, our analysis may overlook opportunities that emerge at finer spatial resolutions. Future studies could further leverage detailed mobility, PV generation, and local electricity network data to optimize EV charging within neighborhoods or individual carparks. Such optimization would allow users to gain direct monetary benefits through PV and V2G and it would align well with concepts of solar energy communities^44,45, thereby further supporting long-term resilience goals such as those outlined in the Singapore Green Plan 2030 (Supplementary Note 15).
Second, a potential limitation arises from privacy constraints associated with mobile phone data and the resulting challenges of accessing such data in other urban regions. The current framework only requires data that is spatially aggregated at the level of urban districts (typical area  >  1 km²). Temporally, the data could also be limited to relatively short driving profiles (i.e., each few days, a new random sample of anonymized users can be selected). This allows for a strong data pre-aggregation by the data provider, which reduces the risks of data misuse, ensures compliance with local and international data protection regulations and thus facilitates data access. Moreover, our framework is not limited to mobile phone data but can be applied to any type of mobility data, such as that generated from agent-based models. Recent advances in transfer learning also enable pre-trained deep learning mobility models to be fine-tuned for specific cities using only small amounts of local data (e.g., from volunteer-based efforts)⁴⁶, making them suitable for more fine-grained analyses.
Third, our optimization framework currently omits additional objectives, such as extending EV battery lifetimes through degradation-aware charging strategies⁴⁷ that promise to further increase the economic viability of the proposed V2G scheme. Fourth, behavioral factors, such as users’ willingness to participate in V2G programs, preferences for charging speed, and battery state-of-charge thresholds^48,49,50, are not yet considered. Incorporating these factors would further enhance the accuracy of the results. Finally, it remains an open challenge to design effective electricity market models and incentive policies^51,52 that encourage EV charging behaviors consistent with the patterns assumed in this work.
In conclusion, our work demonstrates that coordinated bidirectional charging of EVs facilitates the timely, large-scale integration of PV in tropical cities, paving the way for effective implementation that supports the transition to a low-carbon urban future.
This study involved secondary analysis of previously collected, anonymized mobility data and did not constitute human subjects research. Institutional review board approval was therefore not required. Details of the mobility data and their use in the EV mobility modeling are provided in Supplementary Notes 2 and 3.
The base electricity demand (not considering PV and EV integration) was modeled using the bottom-up approach in ref. ⁵³. The electricity demand for each building was thereby simulated using the open-source software ‘City Energy Analyst’⁵⁴. This software determines demand profiles based on building attributes (building use type, building height, floor area, etc.), weather input, and the surrounding environment. The simulated household energy consumption was calibrated against district-level monthly data⁵⁵, and sectoral energy estimates were adjusted using annual consumption data for each sector from the same source. Subsequently, we summed the electricity demands of all buildings and then used half-hourly system demand data⁵⁶ for 2022, averaged over all days, to calibrate the simulated energy demand profiles. Next, the future demand profile for the year 2050 was obtained by scaling the peak demand to 11.5 GW, as projected by the Solar Energy Research Institute of Singapore³³, and assuming that the relative half-hourly variations remain unchanged (Supplementary Note 4). In other words, the same base electricity demand curve was used for all days in our simulation (e.g., we did not differentiate between weekdays and weekends) to better understand the impact of PV and EV mobility dynamics. Finally, to get the district-level half-hourly demand profile (for all sectors), we aggregated the calibrated demands for all buildings in a district.
Due to the limited availability of real-world PV generation data at the level of the analyzed integration scenarios, a conventional simulation-based method was adopted. Specifically, solar PV generation was simulated for each urban district by combining spatiotemporal irradiance data with the generation capacity of available surface areas. Although indirect, such irradiance-based methods have been frequently used in prior studies and have shown reliable performance in urban-scale PV potential assessments^33,57. Building-integrated PV (BIPV) constitutes the largest share of Singapore’s overall PV potential due to the high building density. The potential generation capacity of BIPV at the district level was taken from a prior study⁵³, whereas a minimum irradiation threshold of 750 kWh m⁻² year⁻¹ was used to select available surfaces for PV deployment. Building geometries were assumed to remain unchanged for the year 2050. In addition to buildings, our study considers other potential PV installation areas, including water bodies for floating PV (usable surface  ~ 0.28  × area of water bodies), and designated land areas for ground-mounted PV³³. For both categories, system-level efficiencies were assumed to be the same as those adopted for rooftop PV⁵³. Finally, to match Singapore’s projected PV deployment target³³ of 8.6 GW_p by 2050, the remaining generation was attributed to infrastructure-integrated PV (e.g., noise barriers, PV structures above roads). Aggregated across all districts, this yields a contribution to the installed PV capacity of 9.3% (0.8 GW_p), consistent with the city-wide estimate of 12.6% in Singapore’s PV Roadmap³³ (which provides only an aggregate figure). Then, the PV generation profile of each district was derived based on the mean district-level solar irradiance profile⁵⁸, together with the estimated installed PV capacity. A simplified linear irradiance-output relationship⁵⁹ was assumed to convert irradiance into generation. While we note that a non-linear model may offer higher accuracy at higher spatial resolutions (e.g., individual buildings), the linear approximation is appropriate for the current district-level analysis, where localized variations (e.g., local shading and performance ratios) can cancel out.
Charging demand was simulated for an entire month, after which the daily average was calculated to represent typical daily charging patterns⁶⁰. To explore the maximum possible utilization of EVs as mobile storage units, all vehicles were assumed to be connected to charging stations whenever the parking duration exceeds a pre-determined threshold of 30 minutes^61,62. A vehicle was then charged if its battery state-of-charge (SOC) was below a pre-defined threshold of 20% or if the current SOC was insufficient to cover the upcoming trips^63,64. A backward calculation was used to determine the minimum SOC required to satisfy subsequent trips at each time step, starting from the last trip and working backward. This calculation accounts for the maximum allowable charging opportunity (i.e., when an EV is parked longer than 30 mins) and the SOC limits of each vehicle i (({{{{rm{SOC}}}}}_{i}^{min }le {{{{rm{SOC}}}}}_{i}(t)le {{{{rm{SOC}}}}}_{i}^{max }), with ({{{{rm{SOC}}}}}_{i}^{min }=0) and ({{{{rm{SOC}}}}}_{i}^{max }=1)). Through this backward iteration, the minimum SOC required for the next trip(s) at each step was determined. All EVs were assumed to be equipped with an average battery size of 71 kWh^24,65,66,67. We also assumed a slow charging rate of 7.2 kW, which aligns with a typical AC home charging infrastructure⁶⁶. The detailed simulation process is summarized in Supplementary Note 7. The robustness of our results against variations of these parameters is presented in Supplementary Note 9. All simulations were implemented in MATLAB R2023b (MathWorks).
System-level (i.e., city-scale) EV charging optimization focuses on the benefits for the aggregate power generation needs by flattening the daily demand curve and thus reducing the required installed capacity of non-PV generators that constantly ramp up and down, allowing for steady-state operation with optimal efficiency. For the EV charging optimization, a day was discretized into Δt = 0.25 hour  = 15 min intervals such that each day starts at t = 1 and ends at t = 96. The EV charging and discharging states were determined as follows. Consider a power system in which a total amount of N EVs schedule their charging profiles over T time slots, each with a duration of Δt. Let O(t) and S(t) denote the base (“No PV, no EV”) electricity demand and the solar PV generation at time t, respectively. The net non-EV demand is D(t) = O(t) − S(t). To flatten the aggregate demand profile seen by the grid, the quadratic deviation of the total load is minimized²⁸:
where ({p}_{i}^{{{{rm{ch}}}}/{{{rm{dis}}}}}(t),{bar{p}}_{i}^{{{{rm{ch}}}}/{{{rm{dis}}}}}) and ({eta }_{i}^{{{{rm{ch}}}}/{{{rm{dis}}}}}) denote the charging / discharging power of vehicle i at time step t, its maximum value and the corresponding efficiency. The battery capacity is denoted by c_i. The j-th departure event of vehicle i is given by ({t}_{j}^{{{{rm{dep}}}}}), and ({{{{rm{SOC}}}}}_{i}^{{{{rm{req}}}}}({t}_{j}^{{{{rm{dep}}}}})) is the minimum state-of-charge required to complete the subsequent trip(s) starting at that departure time (pre-computed as in the uncontrolled charging case). We assumed a fixed charging and discharging power for all EVs, equal to the charging rate used for uncontrolled charging. The efficiencies were set as⁶⁸ ({eta }_{i}^{{{{rm{ch}}}}}=0.87) and ({eta }_{i}^{{{{rm{dis}}}}}=0.90). The EV charging optimization problem was solved using Gurobi Optimizer (version 12.0.0, Gurobi Optimization, LLC).
Conversely, this optimization emphasizes more local benefits by minimizing the maximum net demand within each urban district, ensuring a more balanced distribution of energy demand across urban areas:
where k represents the index of districts and z_k represents the peak demand of district k. I_k denotes the set of vehicle indices within district k and K is the total number of districts. ({D}_{k}^{max }) is the peak base demand (without PV and EV integration), which was used to normalize the electricity demand, given that its magnitude varies greatly across the districts.
Further information on research design is available in the Nature Portfolio Reporting Summary linked to this article.
Electricity demand and solar irradiance data are publicly available from the Energy Market Authority of Singapore (https://www.ema.gov.sg/resources/statistics). Data for the derivation of location-specific PV generation potentials are also publicly available, as described in ref. ⁵³. Travel survey and census data are publicly available from the Singapore Department of Statistics (https://www.singstat.gov.sg/publications/reference/cop2020). Although raw mobility data are not publicly available due to privacy considerations, district-level aggregated data to reproduce the findings and figures in this paper are available at https://github.com/tropicalcityv2g-hash/Powering-tropical-cities and have been archived on Zenodo⁶⁹.
All code used in this study is publicly available at https://github.com/tropicalcityv2g-hash/Powering-tropical-cities and has been archived on Zenodo⁶⁹.
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M.S. and H.Y. acknowledge support from the start-up funds provided by Columbia University. Part of this research was conducted at the Singapore-ETH Centre, which is supported and funded by the National Research Foundation and ETH Zurich, with contributions from the National University of Singapore, Nanyang Technological University and the Singapore University of Technology and Design.
Department of Civil Engineering and Engineering Mechanics, Columbia University, New York, NY, USA
Jiazu Zhou, Tianyu Dong, Hongrong Yang & Markus Schläpfer
Future Cities Laboratory Global, Singapore-ETH Centre, Singapore, Singapore
Jiazu Zhou, Tianyu Dong, Seanglidet Yean & Bu-Sung Lee
College of Computing and Data Science, Nanyang Technological University, Singapore, Singapore
Bu-Sung Lee
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J.Z. developed the models, analyzed the empirical data, conducted the numerical simulations, and wrote the manuscript. T.D. contributed to the data analysis and numerical simulations. H.Y. contributed to the power systems modeling. S.Y. and B.-S. L. contributed to the discussion of the results and reviewed the manuscript. M.S. conceived the project, designed the study, supervised the work, and was the lead writer of the manuscript.
Correspondence to Markus Schläpfer.
The authors declare no competing interests.
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Zhou, J., Dong, T., Yang, H. et al. Decentralized electric vehicle charging enables large-scale photovoltaic integration in tropical cities. Nat Commun 17, 3037 (2026). https://doi.org/10.1038/s41467-026-71123-6
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DOI: https://doi.org/10.1038/s41467-026-71123-6
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Nature Communications volume 16, Article number: 8575 (2025) Cite this article
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The interfacial modifications between perovskite and charge-transport layers can arise from strong chemisorption bonds or weak physical adsorption interactions. However, modifications based on physical adsorption are susceptible to detachment, which not only disrupts the original energy level alignment and defect passivation but also introduces new charge recombination centers. Here, we report a fully chemical modification strategy in which the interfacial modifiers undergo an in situ crosslinking-like reaction, forming a localized, chemically bonded layer that seamlessly extends from the bulk of the underlying transport layer to the interface. Perovskite solar cells (PSCs) fabricated with this fully chemical modification strategy achieve a power conversion efficiency (PCE) of 25.52% (certified 25.49%) under standard conditions, representing one of the highest PCEs reported for devices fully fabricated in an ambient atmosphere. In terms of static stability, unencapsulated devices exhibit linear extrapolated T₈₀ lifetimes of 27,000 h during dark shelf storage and 19,000 h under thermal stress at 85 °C, both of which are record-breaking values for dark shelf and thermal stability, respectively. For dynamic stability, the devices maintain a linear extrapolated T₈₀ lifetime of 2,600 h under light-dark cycling, representing the most dynamically stable PSCs reported to date.
Perovskite solar cells (PSCs) are widely recognized as one of the most promising next-generation photovoltaic materials, with the power conversion efficiency (PCE) of single-junction PSCs now exceeding 26%^1,2,3,4. However, a crucial challenge lies in enhancing their durability to achieve a service life comparable to silicon-based cells. The degradation of PSCs is typically triggered by defects at the interfaces or grain boundaries, which not only lead to non-radiative charge recombination losses but also severely compromise the stability of PSCs^4,5. Interface engineering between the perovskite absorption layer and the charge transport layers is crucial for enhancing the efficiency and stability of PSCs. The widespread interest in interface modification can be attributed to the following reasons: (i) the presence of defects in the various functional layers (perovskite absorption layer, electron transport layer, and hole transport layer), which requires passivations; (ii) the incomplete alignment of energy levels between these functional layers, necessitating energy level tuning; and (iii) the potential chemical reactions between metal oxides and perovskites, which adversely affect the efficiency and stability of PSCs. Numerous passivation strategies have been reported, such as inorganic salts, organic salts, ionic liquids, and self-assembled monolayers^{6,7,8,9,10,11,12,13}, aiming to repair interfacial defect states and improve the durability of the devices.
However, modifiers at the interface can be either strongly bonded through chemisorption or weakly bonded through physisorption, with the latter often becoming unstable after prolonged device operation^14,15. During the device fabrication process, modifiers with high solubility are highly susceptible to being dissolved and washed away by solvents such as N, N’-dimethylformamide (DMF) in practical applications, which leads to the inability to maintain the passivation effects that were initially intended, ultimately failing passivation¹⁶. Furthermore, during the storage and operation of the device, the relatively weak binding energy can easily lead to the detachment of modifiers. The occurrence of such detachment can further generate new interface defects, which are undoubtedly highly detrimental to the device’s performance^16,17. In addition, environmental stress factors, such as humidity, heat, and light, can gradually form traps at the bottom of the perovskite active layer^18,19. The formation of these traps can lead to severe ion migration at the interface, thereby greatly affecting the stability of the device^20,21,22,23. Developing failure-resistant interface modification methods is crucial for enhancing device stability under both static conditions (constant environmental parameters such as fixed temperature, humidity, or continuous illumination) and dynamic conditions (simulating real-world scenarios including thermal cycling, light-dark cycling, or actual outdoor exposure).
Here, we first confirmed the detachment of interface modification materials (potassium chloride, guanidine hydrochloride, and methylammonium acetate) commonly used in normal (n-i-p) devices through theoretical calculations and experimental validation. Then, we take the typical SnO₂ electrode in the n-i-p structure as an example and propose a comprehensive chemical adsorption strategy. Specifically, we first pre-embed diethylenetriaminepentaacetic acid (DTPA) molecules within the SnO₂ layer, and then introduce zolephonic acid (Zol) on its surface to promote an in situ cross-linking-like reaction between the two modifiers, thereby establishing a local full chemical adsorption layer from the interior of the SnO₂ layer to the bottom of the PVK layer. The core purpose of this method is to significantly enhance the extraction and migration capabilities of interface charges and ensure that the modifiers do not fail. Ultimately, the PCE was significantly improved to 25.52% (certified 25.49%), one of the highest PCEs for devices fully fabricated in an ambient atmosphere. In addition, the target device showed excellent stability in multiple tests, such as dark storage, thermal stability, light-dark cycling tests, and maximum power point (MPP) tracking. It is worth mentioning that these unencapsulated devices exhibited linear extrapolated T₈₀ lifetimes of 27,000 h during dark shelf storage and 19,000 h under thermal stress at 85 °C, and they also maintained a linear extrapolated T₈₀ lifetime of 2600 h under light-dark cycling. This represents the highest performance in all standard stability tests for air-processed PSCs reported to date.
We focused on investigating the anchoring capability of modifiers on oxide electrodes. Common modifiers can be primarily categorized into ionic modifiers and molecular modifiers. For ionic modifiers, their binding to the oxide surface does not strictly form ionic bonds but rather primarily involves electrostatic adsorption, which constitutes a physical interaction. In the case of molecular modifiers, their binding to the oxide surface is mainly governed by relatively weak hydrogen-bonding interactions. These interactions are relatively low in energy, making the modifier molecules prone to detachment (Fig. 1a). In contrast, DMF molecules in the liquid phase system contain an amide group (-CON-), which exhibits strong binding capability and can engage in robust interactions with most modifiers. In addition, DMF is a highly polar solvent, where the modifier-DMF interaction is typically dominated by strong hydrogen bonding, supplemented by ion-dipole interactions, collectively enhancing the dissolution of the modifier in DMF. These two types of bonds represent relatively strong intermolecular forces, resulting in a comparatively higher adsorption energy. Consequently, during device fabrication, modifiers on the oxide surface are highly susceptible to dissolution and removal by perovskite precursor solvents, ultimately leading to the failure of the intended passivation effect^14,15,16,17.
a Schematic of the adsorption and desorption of modifiers on the oxide electrode surface (before and after washing with DMF). The dashed lines represent weak hydrogen bonds. b DFT calculations of the binding energy between the modifier and the oxide electrode. From left to right: SnO₂/KCl, SnO₂/Gua, and SnO₂/MAAc. The inset shows their binding energies with DMF. All relevant visualization and interpretation are assisted by multiwfn^51,52,53 and VMD⁵⁴. c‒e Binding energies of the modifier with the oxide and with DMF. f‒h XPS spectra of each electrode before and after washing with DMF. f K 2p core level of SnO₂/KCl. The numbers in the figure represent the ratio of the K 2p peak area to the lattice O peak area. g N 1 s core level of SnO₂/Gua. The numbers in the figure represent the ratio of the N 1 s peak area to the lattice O peak area. h C 1 s core level of SnO₂/MAAc. The numbers in the figure represent the ratio of the C 1 s peak area to the lattice O peak area.
To validate these hypotheses, we selected three representative modifiers to evaluate their anchoring effect on oxide electrodes. The structural formulas of these modifiers are presented in Supplementary Fig. 1. Specifically, inorganic salts (potassium chloride, KCl), organic salts (guanidine hydrochloride, CH₅N₃·HCl), and ionic liquids (methylammonium acetate, MAAc) were used to modify the SnO₂ electrode commonly used in n-i-p type devices. We employed density functional theory (DFT) calculations to determine the binding energies of the aforementioned three modifiers with the electrodes, as well as their binding energies with the typical solvent DMF used in perovskite precursors (Fig. 1b). As shown in Fig. 1c‒e, the adsorption energies between all modifiers and DMF were higher than those with the electrodes. We rinsed the modified electrodes with DMF and conducted X-ray photoelectron spectroscopy (XPS) analysis. After rinsing the KCl-modified SnO₂ electrode with DMF, the intensity of the K 2p peak decreased (Fig. 1f), and the ratio of the K 2p_3/2 peak area to that of the lattice O atoms dropped from 19.0% to 7.7% (Supplementary Fig. 2a and Supplementary Table 1), indicating desorption of KCl from the SnO₂ electrode surface. For the CH₅N₃·HCl-modified SnO₂ electrode, after rinsing with DMF, the intensity of the N 1 s peak decreased (Fig. 1g), and the ratio of the N 1 s peak area to that of the lattice O atoms dropped from 22.4% to 15.9% (Supplementary Fig. 2b and Supplementary Table 2), representing desorption of CH₅N₃·HCl from the SnO₂ electrode surface. In Fig. 1h, after rinsing the MAAc-modified SnO₂ electrode with DMF, the intensity of the C 1 s peak decreased, and the ratio of the C 1 s peak area to the lattice O atoms decreased from 18.1% to 12.3% (Supplementary Fig. 2c and Supplementary Table 3), indicating desorption of MAAc from the SnO₂ electrode surface¹⁷. These experimental results are consistent with the theoretical calculation results. In addition, contact angle test results also confirmed this conclusion (Supplementary Fig. 3).
We strive to minimize the desorption of electrode modifiers without affecting the normal perovskite preparation process. Taking the SnO₂ electrode as an example, a fully chemical adsorption method has been proposed. Considering the chelating effect with multiple binding sites, a molecule of DTPA, which is rich in -COOH groups (Supplementary Fig. 4a), was introduced into the SnO₂ colloidal dispersion to prepare SnO₂ thin films. Subsequently, the surface was modified with an aqueous solution of Zol (Supplementary Fig. 4b), which contains two -PO(OH)₂ groups (Supplementary Fig. 5). We speculate that the reaction process is as shown in Fig. 2a. During the heating process at 120 °C, one -PO(OH)₂ group in the Zol molecule will undergo an esterification reaction with the -COOH group in DTPA, forming a phosphodiester bond. Furthermore, the other -PO(OH)₂ group in the Zol molecule will undergo an esterification reaction with the excess -COOH group in another surrounding DTPA, and numerous phosphodiester bonds will bond the molecules together, thereby forming a robust in-situ cross-linked-like covering modification layer on the SnO₂ surface. Supplementary Fig. 6 shows the electrostatic potential of DTPA and Zol. To confirm the specific reactions between DTPA and Zol on the SnO₂ surface, liquid-state proton nuclear magnetic resonance (¹H NMR) testing was conducted. The samples were dissolved in deuterated dimethyl sulfoxide (DMSO-d₆) for verification (Supplementary Fig. 7‒9). Supplementary Fig. 9 shows the characteristic ¹H signal of the phosphodiester bond at δ 3.79 ppm in the product after the reaction between DTPA and Zol at 120 °C. The Fourier-transform infrared spectroscopy (FTIR) in Supplementary Fig. 10 highlights the interaction between -PO(OH)₂ and -COOH groups in SnO₂ electrodes modified with both DTPA and Zol. Specifically, for SnO₂ modified with DTPA, the stretching vibration peak of the C = O bond appears at 1640 cm⁻¹, while for SnO₂ modified with Zol, the P = O bond exhibits a peak at 1640 cm⁻¹. When both modifiers are present, the intensity of the 1640 cm⁻¹ peak decreases and exhibits a slight red shift, indicative of hydrogen bonding or other interactions between -PO(OH)₂ and -COOH groups. This is consistent with the ¹H NMR results.
a Schematic of possible chemical reactions of DTPA and Zol. b DFT calculations of the binding energy of DTPA with SnO₂. c DFT calculations of the binding energy of Zol with SnO₂. d Surface integration of the differential charge density obtained from DFT calculations. e KPFM measurements showing the CPD distribution of SnO₂ films before and after modification. The inset shows surface potential images of Control (left) and Target (right). f‒i XPS spectra of the O 1 s core level before and after washing with DMF for different SnO₂ electrodes: (f) SnO₂, (g) SnO₂-DTPA, (h) SnO₂/Zol, (i) SnO₂-DTPA/Zol. The numbers in the figure represent the ratio of the -OH peak area to the lattice O peak area.
DFT was used to calculate the interactions between DTPA and Zol molecules with the SnO₂ electrode (Fig. 2b‒d). During the simulation process, both -PO(OH)₂ and -COOH can form coordination bonds with uncoordinated Sn. The binding energy (E_b) between DTPA and the top surface of SnO₂ was calculated to be − 0.771 eV, which is lower than the E_b between DTPA and DMF (− 1.140 eV). The E_b between Zol and the top surface of SnO₂ was calculated to be − 0.199 eV, which is lower than the E_b between Zol and DMF (1.171 eV). The differential charge density in Fig. 2d shows significant charge transfer between the two modifier molecules (DTPA and Zol) and SnO₂. The corresponding electron localization function (ELF) images demonstrate electron cloud overlap between Sn and O atoms (Supplementary Fig. 11), further confirming the strong coupling effect between the groups (-COOH in DTPA, -PO(OH)₂ in Zol) and the SnO₂ lattice. These results prove the strong interactions between our selected modifier molecules and the SnO₂ substrate. Changes in elemental binding energies further confirmed the aforementioned mechanism through XPS testing. As shown in Supplementary Fig. 12 and Supplementary Table 4, after modification with DTPA and Zol, the peak of Sn 3 d shifted to higher binding energy, and the proportion of the C = O peak decreased, which can be attributed to the chemical bonding between Sn and the negatively charged O in the modifier molecules²⁴. In addition, peaks for N 1 s and P 2p also appeared after the modification.
In addition, to verify the optimization effect of the modifiers on the SnO₂ surface, Kelvin probe force microscopy (KPFM) and ultraviolet photoelectron spectroscopy (UPS) tests were carried out. Figure 2e shows the change in contact potential difference (CPD) obtained from the KPFM test. The CPD distribution of the films modified with DTPA and Zol became significantly narrower, which implies a reduction in surface defect density, beneficial for effective photocarrier extraction and lower open-circuit voltage (V_oc) loss^25,26. UPS demonstrated the impact of the modifiers on the energy level of the SnO₂ surface and calculated the changes in the SnO₂ band structure (Supplementary Fig. 13). Detailed values are listed in Supplementary Table 5. After co-modification with DTPA and Zol, both the valence band maximum (VBM) and conduction band minimum (CBM) of SnO₂ shift upward. Femtosecond transient absorption spectroscopy (fs-TAS) was employed to investigate the charge carrier dynamics between modified SnO₂ and PVK. In both cases, a strong and immediate ground-state bleaching (GSB) peak at ~ 784 nm was observed upon excitation of the host perovskite absorption (Supplementary Fig. 14a, b). Typically, the GSB signal is proportional to carrier density. For the SnO₂/perovskite stack, the variation in GSB peak intensity with delay time directly reflects the quantity of photogenerated carriers in the conduction and valence bands of the perovskite²⁷. Compared to pristine SnO₂/PVK, weaker GSB signals at identical delay times were exhibited by the SnO₂-DTPA/Zol/PVK sample (Supplementary Fig. 14c, d), along with a higher electron extraction rate (Supplementary Fig. 14e). It is concluded that faster electron transfer from the perovskite to the adjacent modified SnO₂ contact occurs. This can be attributed to the critical role of interface modification in promoting carrier extraction, and it is consistent with the KPFM. More importantly, we rinsed the electrodes before and after modification with DMF. XPS showed that the electrodes co-modified by DTPA and Zol exhibited good anchoring stability (Fig. 2f‒i and Supplementary Table 6). The contact angle tests also yielded consistent results with XPS (Supplementary Fig. 15). Cross-sectional TEM-EDS mapping reveals distinct and homogeneous distribution of P and C elements throughout the SnO₂ layer, demonstrating uniform dispersion of the modifiers within the SnO₂ transport layer(Supplementary Fig. 16).
We explored the impact of interface modifications at the buried interface. DFT theoretical calculations demonstrated the interaction between the Zol closest to the perovskite film and the bottom terminal of the perovskite (Fig. 3a‒c). Figure 3a, b respectively depict the significant differences in charge density between PVK with unsaturated lattice and saturated lattice interacting with Zol molecules. The changes in electron cloud distribution indicate charge gain and loss, with red and blue regions representing electron depletion and accumulation, respectively, due to electron redistribution. In Fig. 3a, the electron density increases on the FA⁺ surface while decreasing on the N atom of the Zol molecule above it, suggesting that Zol bonds with FA⁺ through the N atom, thereby transferring electrons to FA⁺. Similarly, in Fig. 3b, the electron density increases on the Pb atom surface but decreases on the N atom surface, indicating that Zol can also bind to Pb via the N atom, leading to electron transfer to Pb. This is further reflected in the differential charge density analysis (Fig. 3c), where the PVK surface gains electrons, forming a negative charge center, while Zol loses electrons, creating a positive charge center. Consequently, an efficient carrier transfer is established at the Zol/PVK interface. We found that Zol can both bind with FA⁺ and form bonds with non-coordinated Pb²⁺. 1H NMR tests (Fig. 3d, e and Supplementary Fig. S17) showed that Zol caused the characteristic signal of FA⁺ to split, further confirming that Zol can form van der Waals bonds with FA⁺. The variation of the Zol characteristic signal in Supplementary Fig. 18 confirms the interaction between Zol and uncoordinated Pb²⁺. To assess the improvement of the micromorphology and crystal structure of the perovskite film on the SnO₂-DTPA/Zol electrode, we conducted X-ray diffraction (XRD) and scanning electron microscopy (SEM) tests. The XRD spectrum showed that the characteristic peaks of the perovskite film on the SnO₂ electrode before and after modification were essentially the same, while the peak intensity of the perovskite film on the SnO₂-DTPA/Zol electrode was significantly enhanced (Fig. 3f). This indicates that the atomic arrangement orderliness at the lower interface of the modified perovskite film has been significantly improved. The top-view SEM image confirmed that the grain size of the perovskite film on the SnO₂-DTPA/Zol electrode was larger than that of the control film (Fig. 3g). These experimental results prove that the SnO₂-DTPA/Zol electrode is beneficial for the crystallization and growth of the FAPbI₃ film.
DFT calculations of the binding energy between Zol and FAPbI₃ for (a), unsaturated lattice and (b), saturated lattice. c Surface integration of the differential charge density obtained from DFT calculations. d 2D ¹H NMR spectrum of FAPbI₃, and (e) reaction products of DTPA and Zol, as well as the FAPbI₃ mixture. f XRD patterns and (g) SEM images (with particle size distribution histogram below) of FAPbI₃ films grown on different SnO₂ electrodes before and after modification.
We fabricated devices with an n-i-p stack of glass/FTO/SnO₂/FAPbI₃/Spiro-OMeTAD/Au in a full air environment (Fig. 4a). We prepared FAPbI₃ using the one-step solution process (Fig. 4b) and the two-step solution process (Supplementary Fig. 19), respectively. Devices with SnO₂-DTPA/Zol as the electron transport layer (ETL) exhibited the best photovoltaic performance. At a mask area of 0.094 cm², the PCE reached 25.52% (certified 25.49%, Supplementary Fig. 20), with an open-circuit voltage (V_oc) of 1.18 V, a short-circuit current density (J_sc) of 25.59 mA cm^–², and a fill factor (FF) of 84.51% (Supplementary Table 7). This is one of the highest efficiencies for PSCs prepared in a full-air environment (Supplementary Table 8). These parameters are superior to the control devices (PCE = 22.65%, V_oc = 1.14 V, J_sc = 24.12 mA cm⁻², FF = 82.50%). At the same time, compared to the control device, the target device has significantly reduced hysteresis (Supplementary Fig. 21). External quantum efficiency (EQE) testing confirmed the measured J_sc (Fig. 4c). The EQE of the target devices was consistently higher than that of the control devices across the entire visible light absorption region. By integrating the EQE over the AM 1.5 G standard solar spectrum, the integrated current density J_sc for the control and target devices were calculated to be 23.8 mA cm⁻² and 24.9 mA cm⁻², respectively, which closely matched the current density J_sc measured under the solar simulator. In addition, the co-modification with Zol and DTPA was also tried in a large-area submodule. The fabricated submodule with an aperture area of 30 × 30 cm² showed a PCE of 16.49% (Supplementary Fig. 22). These results further indicate that DTPA and Zol reduced the defect density at the SnO₂/FAPbI₃ interface, minimized interface losses, and improved the V_oc and PCE of the PSCs.
a Schematic of the n-i-p PSC device structure and cross-sectional SEM image. b J-V curves of PSCs with SnO₂, SnO₂-DTPA, SnO₂/Zol, and SnO₂-DTPA/Zol as the ETL (inset shows a photo of the best-performing device). c Corresponding EQE spectra and integrated J_sc. Optical properties of FAPbI₃ films grown on different SnO₂ electrodes before and after modification: (d) UV-vis; (e) PL; (f) TRPL spectra; and (g) SCLC curves.
To further verify the passivation effect of DTPA and Zol on the defects at the SnO₂/FAPbI₃ interface, we conducted relevant tests on the photoelectronic properties of thin films. The results of ultraviolet-visible absorption (UV-vis) spectra indicated that the absorption intensity of the SnO₂-DTPA/Zol perovskite film was slightly higher than that of the initial sample (Fig. 4d). The photoluminescence (PL) spectra described the steady-state optical properties of the perovskite films (Fig. 4e). The fluorescence absorption peak positions of all samples were beyond 800 nm. Compared to the pristine SnO₂/PVK sample, the SnO₂-DTPA/Zol/PVK sample exhibits significantly reduced photoluminescence peak intensity, demonstrating that the co-modification enhances the electron extraction capability of the SnO₂ ETL, thereby facilitating more efficient charge transfer from the perovskite to the ETL²⁸. The time-resolved photoluminescence (TRPL) spectra described the carrier dynamics of the perovskite films (Fig. 4f and Supplementary Table 9). The carrier lifetimes (τ₁ = 24.48 ns, τ₂ = 199.22 ns, τ_ave = 90.47 ns) of the perovskite film deposited on SnO₂-DTPA/Zol were shorter than those of the control sample (τ₁ = 54.25 ns, τ₂ = 354.69 ns, τ_ave = 159.97 ns). The reduction in carrier lifetime confirmed a significant enhancement in charge extraction capability at the modified ETL/perovskite interface, with a significant decrease in radiative recombination of carriers²⁹. The defect density was assessed in electron-only devices (FTO/ETL/perovskite/PCBM/Ag) using space-charge-limited current (SCLC) (Fig. 4g). The SCLC curve is divided into three regions. In the low-bias left region, the current varies linearly with voltage, which is considered an ohmic contact. Then, as the bias voltage increases, it gradually enters the trap-filling region, where carriers fill traps through continuous injection³⁰. The intersection of these two regions is called the trap-filling limit voltage (V_TFL). The high-bias region of the SCLC curve represents a quadratic relationship between current and voltage³¹. After modifying SnO₂ with DTPA and Zol, the defect density (N_t) was reduced from 3.68 × 10¹⁵cm⁻³ to 2.26 × 10¹⁵cm⁻³, which decreased the defect density caused by interfacial recombination and promoted effective charge extraction and transport. This result is consistent with the PL and TRPL test results.
The Mott-Schottky curves of the PSCs were obtained under dark conditions to explore the mechanisms of V_oc and PCE (Supplementary Fig. 23)³². The built-in potential of the target devices (0.90 V) is greater than that of the original devices (0.86 V), indicating that the electric field at the modified SnO₂/FAPbI₃ interface has become stronger. This can promote charge separation, prevent charge accumulation at the interface, and enhance the transport performance of charge carriers. As shown in Supplementary Fig. 24, the formation of dark current is due to the migration of charge carriers caused by defects present in the PSCs²⁴. Within the voltage range of − 0.6 to 0.6 V, the dark current density of the target devices is lower than that of the control devices, further confirming the passivation effect of the modified SnO₂/FAPbI₃ interface. We also studied the electrochemical performance and charge recombination of the PSCs using electrochemical impedance spectroscopy (EIS) (Supplementary Fig. 25). It was observed that compared to the control devices (2850 Ω), the target devices (4510 Ω) exhibit a higher recombination resistance (R_rec), indicating a reduction in carrier recombination losses within the PSCs³³.
To investigate the phase stability, we conducted aging tests on FAPbI₃ films with different electrodes using an ultraviolet lamp and a hot stage. Supplementary Fig. 26 shows that the initial film almost completely decomposed after aging for 13 h under an ultraviolet lamp at 254 nm (T_ambient = 35 °C, RH = 85%), with a significant reduction in the intensity of the characteristic peaks of its black phase in XRD. In contrast, the FAPbI₃ film on the SnO₂-DTPA/Zol electrode still maintained a clear black phase after aging for 13 h. Similarly, the results after aging at 110 °C (T_ambient = 35 °C, RH = 85%, natural light) were consistent with those under the ultraviolet lamp (Supplementary Fig. 27). Furthermore, the microstructural morphology (Supplementary Fig. 28) and optical absorption properties (Supplementary Fig. 29) of all thin films were characterized before and after aging, with the test results being fully consistent with the XRD data. These results are attributed to the fixation of the terminal FA⁺ cations at the bottom of FAPbI₃ by DTPA and Zol, and the repair of interfacial defects, leading to a significant improvement in the phase stability of FAPbI₃. Here, we define an environment with constant humidity, temperature, or light conditions as a static environment, while an environment where these conditions change continuously over time is referred to as a dynamic environment. Currently, many aging tests for PSCs in laboratories are conducted under static environmental conditions, yielding promising stability results. However, during outdoor operation, PSCs are subjected to continuously changing humidity, temperature, and light conditions due to seasonal weather variations and the daily cycles of sunrise and sunset. Therefore, it is crucial to investigate both the static and dynamic stability of PSCs. Regarding static stability, the dark storage stability experiment was conducted on devices with an area of 0.094 cm² according to the ISOS-D-1 protocol³⁴ (Fig. 5a). The unencapsulated devices processed with both DTPA and Zol retained over 97% of their initial PCE after being stored for 2750 h in an air environment (Relative humidity: 20‒40%) at 23 ± 4 °C, while the control devices’ PCE dropped to nearly 80% of their initial value under the same conditions. The thermal stability experiment was conducted on devices with an area of 0.28 cm² according to the ISOS-D-2 protocol (Fig. 5c). The unencapsulated target devices retained over 97% of their initial PCE after being treated on a hot plate at 85 °C in a nitrogen environment for 950 h, whereas the control devices’ PCE dropped to about 80% of their initial value under the same conditions. For dynamic stability, the light-dark cycling experiment was conducted on devices with an area of 0.28 cm² according to the ISOS-LC-1 protocol (Fig. 5e). Supplementary Fig. 30 shows the light-dark cycling procedure. The unencapsulated target devices retained 93% of their initial PCE after 1008 h, while the control devices’ PCE decreased to 67% of their initial PCE. After pre-exposure for 1000 h under damp heat conditions, we further conducted MPP tracking tests on devices with an area of 0.28 cm² according to the ISOS-L-1 protocol to assess the operational stability under harsh conditions (Fig. 5g). The damp heat treatment induced pre-aging of the FAPbI₃ film, and after the start of the MPP tracking experiment, illumination accelerated the phase transformation and decomposition of FAPbI₃ within the devices³⁵. Consequently, the PCE of the control devices rapidly decreased to below 60% of their initial performance after 500 h. However, the target devices were still able to retain over 80% of their PCE. Thermal cycling experiments were performed on devices with an active area of 0.04 cm² (Supplementary Fig. 31). Each cycle consisted of: (1) aging the devices in a vacuum drying oven at 65 °C for 24 h, followed by (2) storage in a N₂ glovebox under dark conditions at room temperature for 24 h. After 960 h, the unencapsulated target devices retained over 80% of their initial PCE, while the control devices degraded to below 40% of their initial PCE. Real outdoor stability testing was also performed on 0.04 cm² devices (Supplementary Fig. 32). The encapsulated devices were aged under actual outdoor conditions. After 500 h, the target devices maintained approximately 80% of their initial PCE, whereas the control devices degraded to less than 20% of their initial PCE. It is worth mentioning that we performed linear extrapolation^19,36 on the data from dark storage, thermal stability, and light-dark cycling tests, and derived the theoretical T₈₀ values of approximately 27,000 h, 19,000 h, and 2600 h, respectively (Fig. 5b, d, and f). As far as we know, these results position them among the most statically and dynamically stable PSCs³⁷ (Supplementary Tables S10‒12).
a Stability study of PSCs. Evolution of the efficiency of PSCs under dark storage conditions in an indoor air environment (ISOS-D-1). c Evolution of the efficiency of PSCs under heating conditions at 85 °C (ISOS-D-2). e Efficiency evolution of PSCs under light-dark cycling tests (12 h on/12 h off) (ISOS-LC-1). b, d, and f Corresponding linear extrapolation of lifetime results. g MPP tracking of PSCs after 1000 h of damp heat pre-treatment.
In summary, we have demonstrated that the co-decoration of SnO₂ electrodes with DTPA and Zol can improve the quality of the SnO₂/FAPbI₃ interface while ensuring that the modifiers do not detach or fail due to weak chemical bonding. We have elucidated that the mechanism of action is related to the in situ reaction of the modifiers on the SnO₂ surface. By pre-embedding DTPA molecules within the SnO₂ film and then introducing Zol to the film surface, the two modifiers undergo an in situ cross-linking-like reaction at high temperatures of 120 °C, thereby forming a robust chemical coverage area between the oxide electrode and FAPbI₃. At the same time, the part of Zol closest to the perovskite film can bond with FA⁺ cations, effectively preventing the escape of perovskite terminal cations and reducing defect-induced interfacial recombination losses. Therefore, this strategy can achieve a PCE of 25.52% under standard conditions, one of the highest PCEs for devices fully fabricated in an ambient atmosphere. These resulting unencapsulated cells also exhibit exceptional stability, successfully passing multiple standard stability tests, including dark storage, thermal stability, light-dark cycling, and MPP tests. In addition, we have predicted, using linear extrapolation, that the T₈₀ storage lifetime is ≈ 27,000 h, the storage life at 85 °C is ≈ 19,000 h, and the light-dark cycle lifetime is ≈ 2600 h. To our knowledge, this represents the highest combined performance in all standard stability tests for PSCs fabricated by the air method reported to date.
All materials have not been further purified since purchase. FTO/glass and Methylammonium iodide (MAI, > 99.99%) were obtained from Advanced Election Technology. SnO₂ colloid precursor (tin(IV) oxide, Lead (II) iodide (PbI₂, 99.999%), Phenethylammonium iodide (PEAI, 99.5%), Spiro-OMeTAD (99.5%), PTAA (MOS) were purchased from Xi’an Polymer Light Technology Corp. Formamidinium iodide (FAI, > 99.99%) and Methylammonium chloride (MACl, > 99.99%) were purchased from Greatcell Solar Materials Pty Ltd. N, N-dimethylformamide (DMF), dimethyl sulfoxide (DMSO), isopropanol (IPA) and chlorobenzene (CB), 4-tert-butylpyridine (tBP), acetonitrile (Ace), bis(trifluoromethylsulfunyl)-imide lithium salt (Li-TFSI; 99.95%), were obtained from Sigma-Aldrich. FK209 Co(III) TFSI were purchased from Luminescence Technology Corp. Diethylenetriaminepentaacetic acid (DTPA, 99%), Zolephonic acid (Zol, 99%) were purchased from Aladdin.
SnO₂ Substrate Preparation: The FTO glass was successively cleaned in detergent, deionized water, and ethanol for 30 min by an ultrasonic cleaner. The clean FTO was treated with an ultraviolet ozone machine for 30 min. The SnO₂ solution was mixed with water at a volume ratio of 1:3 and spin-coated on the FTO at 3000 rpm for 30 seconds, followed by annealing at 150 °C for 30 min in air. For the target devices, 0.1 mM DTPA was pre-added to the SnO₂ solution. After the annealing of SnO₂ film, a Zol solution (2 mM Zol in ultrapure water) was spin-coated onto the SnO₂ film at 3000 rpm for 30 seconds, followed by annealing at 120 °C for 5 minutes.
PSCs Fabrication: The whole process of the PSCs fabrication was carried out in an ambient air environment (room temperature and 20‒50% relative humidity). Perovskite films were fabricated by either one-step spin-coating or two-step spin-coating. For surface passivation, 4 mg/mL PEAI in isopropanol was spin-coated on the perovskite film at 5000 rpm for 30 s without further treatment. The hole transfer material (HTM) solution was prepared by mixing 90 mg Spiro-OMeTAD, 35 μl bis(trifluoromethane) sulfonimide lithium salt (Li-TFSI) solution (260 mg Li-TFSI in 1 ml acetonitrile), 30 μl 4-tertbutylpyridine (tBP), and 30 μl of FK209 Co(Ⅲ) TFSI salt (375 mg/mL in acetonitrile). Then, the HTM solution was deposited on the top at 3000 rpm for 30 s in air without annealing. Finally, 80 nm Au was deposited to form an electrode by thermal evaporation under 5 × 10⁻⁴Pa. Before the J-V test, a commercial anti-reflection layer (Shengyu Tech.) is carefully stuck on the glass side for better light transmittance.
The perovskite films, which were fabricated by the two-step solution process:
Firstly, 692 mg PbI₂ was dissolved in 1 ml DMF: DMSO (v: v = 9:1), spin-coated on the SnO₂ electrode at 1500 rpm for 30 s, and annealed at 70 °C for 1 min. After cooling down to room temperature, the organic solution (92.5 mg FAI, 6.5 mg MAI, and 9.5 mg MACl in 1 mL IPA, stirred for more than 2 h) was spin-coated onto the PbI₂ film at 2500 rpm for 3 s, 1350 rpm for 15 s and 1700 rpm for 12 s. The film was annealed at 150 °C for 15 min. All spin-coating and annealing processes were performed under ambient air conditions (room temperature and 20‒50% R.H.).
The perovskite films, which were fabricated by the one-step solution process³⁸:
The perovskite precursor solution was prepared by dissolving 810 mg of black-phase FAPbI₃, 35 mol% of MACl, and 1 mol% of acetylcholine chloride in DMF and DMSO (8:1 v/v) at 60 °C. The perovskite layers were then spin-coated at 1000 rpm for 10 s and 5000 rpm for 15 s, and 1 mL of ethyl ether was dripped onto the electrode during spin-coating. The perovskite layers were annealed at 120 °C for 40 min, and the electrode was cooled. All spin-coating and annealing processes were performed under ambient air conditions (room temperature and 20‒50% R.H.).
The stability analysis devices:
Under heating conditions, PEAI could be gradually converted into the PEA₂PbI₄ phase, leading to reduced device operational lifetime³⁹. Consequently, we removed the PEAI passivation layer for all thermal-related stability tests. In addition, given the intrinsic instability of Spiro-OMeTAD as an HTL^40,41,42, we adopted a Spiro-OMeTAD/PTAA hybrid HTL for most stability evaluations, while employing pure PTAA HTL for a limited number of tests to ensure enhanced stability.
Specifically, for thermal stability testing, the perovskite films received no surface modification with PEAI or any other agent. The Spiro-OMeTAD/PTAA mixed solution (90/15 mg/mL in chlorobenzene) was supplemented with 35 μL Li-TFSI solution (260 mg/mL in acetonitrile), 30 μL tBP, and 30 μL FK209 Co(Ⅲ) TFSI salt (375 mg/mL in acetonitrile), followed by spin-coating deposition at 5000 rpm for 30 s.
For storage, MPPT, and light-dark cycling tests, the perovskite films were modified with OAI (5 mg in 1 mL isopropanol) through spin-coating at 4000 rpm for 30 s and subsequently annealed at 150 °C for 10 min to form a 2D perovskite surface layer. The Spiro-OMeTAD/PTAA mixed solution (90/7 mg/mL in chlorobenzene) was supplemented with 35 μL Li-TFSI solution (260 mg/mL in acetonitrile), 30 μL tBP, and 30 μL FK209 Co(Ⅲ) TFSI salt (375 mg/mL in acetonitrile), and deposited via spin-coating at 5000 rpm for 30 s.
Regarding thermal cycling and outdoor storage stability tests, the perovskite films remained unmodified with PEAI or other surface treatments. The PTAA solution (20 mg/mL in chlorobenzene) was mixed with 10 μL tBP and 2.6 μL Li-TFSI solution (260 mg/mL in acetonitrile), then spin-coated at 5000 rpm for 30 s.
The ground-state geometries of the investigated molecules were optimized using the B3LYP functional with the 6-311 G (d, p) basis set^{43,44,45,46,47,48}. The absence of imaginary frequencies in the optimized structures confirms that all geometries correspond to energy minima. Density functional theory (DFT) calculations were performed using the Gaussian 09 program⁴⁹.
The perovskite (FAPbI₃)/zol interface system was optimized using the generalized gradient approximation (GGA) with the Perdew-Burke-Ernzerhof (PBE) exchange-correlation functional in CP2K⁵⁰. The corresponding input files are constructed with the assistance of multiwfn. Calculations identify the FAPbI₃ (001) plane as the most stable surface. To reduce computational costs, a 4 × 4 × 3 FAPbI₃ perovskite supercell was constructed. The electron wave functions were expanded using a plane-wave basis set with a kinetic energy cutoff of 400 eV. For K-point sampling, a 1 × 1 × 1 Monkhorst-Pack grid was applied in the irreducible Brillouin zone. A 20 Å vacuum region was added to the outer PbI₂ surface to avoid spurious interactions. A similar treatment was performed on the exposed lattice to study its interaction with FA cations. To standardize the initial configuration, all molecules were placed equidistantly on the perovskite surface. Self-consistent iterative convergence was achieved at a threshold of 1.0 × 10⁻⁴eV/atom, and atomic positions were relaxed until the maximum force on each atom was below 0.05 eV/Å.
Similar methods were used to optimize and calculate the electron layer/modifier interface systems. According to the literature, tin oxide (SnO₂) was modeled using the [110] plane, while nickel oxide (NiO) was modeled using the [100] plane. To reflect practical conditions, oxygen vacancies were introduced into the electron layers as appropriate^11,24.
The binding energy of DMF/modifier interactions was calculated based on electron layer/modifier simulations. The adsorption energy (E_ads) was determined using the formula:
Here, E_Total is the total energy of the system, E_base is the energy of the base material, and E_app is the energy of the adsorbed molecule or modifier.
The current density–voltage (J–V) curves were measured using an AM 1.5 G solar simulator equipped with a Xenon lamp (USHIO) and a Keithley 2450 source meter. The light intensity was calibrated to be 100 mW/cm² using a NIST-certified monocrystalline Si solar cell. For all measurements, a non-reflective metal mask with an aperture area of 0.094 cm² was used to cover the active area of the device to avoid light scattering through the sides. The steady-state photoluminescence (PL) and time-resolved photoluminescence (TRPL) were performed via 450 nm laser in FLS 1000, Edinburgh Instruments. The surface chemical environment of perovskite films was obtained by X-ray photoelectron spectrometer with binding energy referenced to C 1 s peak at 284.8 eV (XPS, Thermo Scientific ESCALAB Xi +). The Nuclear magnetic resonance (¹H-NMR) spectra were measured with a 400-MHz spectrometer (BRUKER AVANCE NEO 400 M). Ultraviolet-visible (UV-vis) spectra were measured with a Varian Cary 5. The SEM images of the perovskite films were measured by a field-emission scanning electron microscope (FE-SEM, Zeiss Sigma 300). The KPFM images of the perovskite films were taken by Horiba JY Labram EVO. The Mott-Schottky curves and EIS data were measured by an electrochemical workstation (AMETEK PARSTAT 3000-DX). Crystal structure information was gathered using a powder X-ray diffractometer (PXRD, Bruker D8 Advance) equipped with a Cu Kα radiation source. Additional information on structures and chemical bonding was measured using Fourier-transformed infrared spectroscopy (FTIR, Thermo Scientific Nicolet iS50).
Further information on research design is available in the Nature Portfolio Reporting Summary linked to this article.
The data that supports the findings of the study are included in the main text and supplementary information files or upon request from the corresponding authors. Source data are provided in this paper.
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This work was supported by financial support from the National Natural Science Foundation of China (52203359). This work was also supported by the National and Jiangsu Province NSF (T2293691, BK20212008) of China, National Key Research and Development Program of China (2019YFA0705400), the Research Fund of National Key Laboratory of Mechanics and Control for Aerospace Structures (MCMS-I-0422K01), the Fundamental Research Funds for the Central Universities (NC2023001, NJ2023002, NJ2022002) and the Fund of Prospective Layout of Scientific Research for NUAA (Nanjing University of Aeronautics and Astronautics). We acknowledge the characterization support of the Center for Microscopy and Analysis at Nanjing University of Aeronautics and Astronautics. The research work is supported by the supporting funds for talents of Nanjing University of Aeronautics and Astronautics. J.P. and S.I.S. acknowledge support from the Basic Science Research Leader Program (Grant NRF-2018R1A3B1052820) through the National Research Foundation of Korea (NRF) funded by the Ministry of Science, ICT & Future Planning (MSIP).
State Key Laboratory of Mechanics and Control of Mechanical Structures, Key Laboratory for Intelligent Nano Materials and Devices of the Ministry of Education, Institute for Frontier Science, Nanjing University of Aeronautics and Astronautics, Nanjing, PR China
Luyao Li, Cheng Wang, Weicun Chu, Yiming Dai, Jiaxing Gao, Zeliang Wei, Xiaoming Zhao, Xuchen Nie, Riming Nie & Wanlin Guo
School of Materials Science and Engineering, Shaanxi University of Science and Technology, Xi’an, PR China
Luyao Li & Lixiong Yin
Department of Energy Engineering, School of Energy and Chemical Engineering, Ulsan National Institute of Science and Technology, Ulju-gun, Ulsan, Republic of Korea
Jaewang Park & Sang Il Seok
Shanghai Shengjian Technology Co., Ltd., Shanghai, China
Qiankai Ba & Kaifeng Wang
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Riming Nie conceived and directed the project. Luyao Li, Riming Nie, Sang Il Seok, Lixiong Yin and Wanlin Guo reviewed the experiment, analyzed the data, and wrote the manuscript, and all authors discussed the results and commented on the manuscript. Luyao Li fabricated films/devices and conducted XRD/UV-vis/SEM/XPS/UPS/PL/TRPL/FTIR/Photovoltaic performance characterization/stability measurements. Cheng Wang performed density functional theory calculations. Jaewang Park and Weicun Chu helped fabricate and characterize the devices. Weicun Chu conducted KPFM characterizations. Weicun Chu and Yiming Dai helped carry out the EQE/SCLC/Dark J-V curve and analyze data. Qiankai Ba and Kaifeng Wang helped in fabricating the large-area submodule and tested the efficiency. Cheng Wang and Jiaxing Gao carried out the NMR measurement. Yiming Dai and Jiaxing Gao helped collect stability test data. Zeliang Wei helped collect and analyze contact angle test and J-V curve data. Xiaoming Zhao and Xuchen Nie revised the manuscript.
Correspondence to Lixiong Yin, Sang Il Seok or Riming Nie.
The authors declare no competing interests.
Nature Communications thanks the anonymous, reviewer(s) for their contribution to the peer review of this work. A peer review file is available.
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Li, L., Wang, C., Chu, W. et al. Fully chemical interface engineering for statically and dynamically stable perovskite solar cells. Nat Commun 16, 8575 (2025). https://doi.org/10.1038/s41467-025-63588-8
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DOI: https://doi.org/10.1038/s41467-025-63588-8
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India's installed renewable energy capacity has surged past 150 GW, driven by a record 44.61 GW of solar installations in fiscal year 2025-26. Wind power also saw its highest-ever installations at 6.05 GW. This expansion cements India's position as the third-largest globally in renewable energy, with total non-fossil capacity reaching 223.27 GW.
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Solar power installations surged in fiscal year 2025-26, reaching 44.61 GW, boosted by a record 6.65 GW added in March alone. This significant solar expansion shows India's strong push towards its clean energy goals.
Wind power capacity also hit a new high, with 6.05 GW installed in FY26, exceeding the previous record of 5.2 GW from 2016-17. These strong results in both solar and wind signal a broad expansion strategy for renewable sources.
Across all sources, renewable energy additions surpassed 50 GW in FY26. This brings the total non-hydro capacity to 223.27 GW, and the overall capacity, including large hydro projects, to 283.46 GW. Within this, rooftop solar installations alone exceeded 25 GW, reaching 25.73 GW.
Union Minister Pralhad Joshi pointed to Distributed Renewable Energy (DRE) from solar as a key driver, adding 16.3 GW to the year's capacity. Initiatives like PM KUSUM and rooftop solar programs supported this crucial segment.
The increase of 55.29 GW in non-fossil fuel capacity during FY26 represents the largest yearly jump on record, far exceeding the previous high of 29.5 GW in FY25. This strong progress reinforces India's role in the global shift to cleaner energy.
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An international study reported by pv magazine indicates that integrating utility-scale solar photovoltaic arrays with a specific form of gravity-based storage could achieve a very low levelized cost of energy in certain parts of the United States. The research suggests that hydraulic hydro storage, paired with solar generation, could provide gigawatt-hour-scale, cost-competitive, and reliable long-duration storage with minimal environmental footprint.
The analysis examined 936 sites nationally using a multi-objective capacity optimization model to evaluate the technical and economic feasibility of such large-scale integrations. According to the researchers, this work establishes a first comprehensive geospatial benchmark for giga-scale hydraulic hydro storage combined with utility-scale solar photovoltaics, moving beyond prior studies that focused on smaller systems or single-site models.
The proposed system configuration involves a solar array, an aggregated commercial district load representing two thousand buildings, and the hydraulic hydro storage unit acting as an energy buffer. When solar production exceeds demand, surplus electricity drives a reversible pump-turbine to lift a solid rock piston, storing energy as gravitational potential. To generate power, the weight of the piston descends, driving pressurized water through the turbine.
The construction method would utilize standard mining techniques to cut the piston from bedrock and install a sealing membrane. A key characteristic is that storage capacity scales dramatically with the piston’s radius, enabling very large-scale energy reserves. The scientists noted that, unlike traditional pumped hydro storage, this approach does not depend on significant elevation differences, potentially broadening where it can be deployed.
For the modeling, photovoltaic panels were assigned a specific efficiency and optimal orientation, while the storage system was assumed to have an 80% round-trip efficiency with eight hours of storage duration. Load profiles were developed from typical meteorological year data, and an optimization routine balanced achieving a low levelized cost of energy against maintaining high reliability, measured by loss of load probability.
The study identified that in high-potential regions, the levelized cost of energy can reach a notably low figure because revenue from exporting surplus solar power helps offset capital and operational expenses. The system was reported to achieve high self-sufficiency at a district scale, with a levelized cost of storage that is competitive with utility-scale batteries for long-duration applications. Across the analyzed climates, storage requirements and photovoltaic capacity needs varied, with a majority of locations achieving an asset-level levelized cost below a specified threshold while maintaining strong reliability performance.
The academics emphasized that the feasibility of such giga-scale projects is heavily dependent on local policy frameworks. They identified state-specific power purchase agreement structures and regional photovoltaic capital costs as primary factors determining a system’s relative performance. For the technology to reach its full potential, site selection must align favorable geological conditions with supportive electricity market designs.
The findings were detailed in a paper published in the journal Energy Conversion and Management, with contributions from researchers at the University of Waterloo in Canada and Cairo University in Egypt.
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Bonita Springs Utilities, Inc., is proceeding with a floating solar array at its East Water Reclamation Facility, after board approval of the project.
This includes the construction of a 1.5-megawatt “alternating current floating photovoltaic system” that will be installed on an existing pond near the utility’s EWRF and is expected to offset approximately 60% of the facility’s energy demand from the electric grid.
“This project represents a thoughtful investment in our utility’s future,” said Richard Garner, president of the BSU Board of Directors. “We have evaluated solar opportunities for many years, and the timing is right to move forward in a financially responsible and operationally sound way. This initiative helps stabilize energy costs, strengthens our infrastructure and reflects our commitment to responsible stewardship on behalf of our members.”
The floating solar system will operate under a net metering agreement with Florida Power & Light. At peak performance, the system is expected to supply up to two-thirds of the facility’s energy needs.
“Energy is one of our biggest operating costs at the EWRF, and this project will help us offset a significant portion of that demand with on-site power generation,” said Andy Koebel, executive director of BSU. “It’s a practical investment that helps manage costs over the long-term, strengthens our system and puts us in a better position moving forward.”
Construction of system components is already underway offsite. Onsite installation is anticipated to be completed this fall, with the system expected to be fully operational by the end of the year. BSU expects to begin realizing energy and cost benefits in 2027.
Drowning is the leading cause of accidental death among Florida children ages one to four.
The YMCA of Southwest Florida offers water safety and swim programs for children of all ages throughout the region, including its core “Safety Around Water” course, teaching essential skills, and swim lessons” to build confidence and proficiency. 
The Y also provides lifeguard training for certification and a competitive youth swim team.
To benefit the Y’s programs, Suncoast Custom Pools will host its second annual Suncoast Signature Cup charity golf tournament on Friday, May 15, at the Quarry Golf Club, 8950 Weathered Stone Dr. in North Naples. The event brings together Southwest Florida’s top professionals, partners and community champions. More than 100 golfers and volunteers participated in last year’s event, raising $100,000, which funded swim lessons for more than 250 children.
“We anticipate that this year’s golf tournament will build upon the success we had in our inaugural year in helping the YMCA of Southwest Florida provide these vital water safety education and swim programs in our community,” said Josh McKenna, Owner and CEO of Suncoast Custom Pools. “We are proud to help prevent further youth drownings through this annual fundraising event and our Pools with A Purpose partnership in which we donate a package of swim lessons to a child in need for every new pool we build.”
The Suncoast Custom Pools Signature Cup charity event will feature an 18-hole scramble.
For information, visit sccpools.com/suncoast-signature-cup.
Baker Senior Center of Naples will present “Caring for the Caregiver: Resources, Support and Strategy” on Thursday, April 23 for those caring for loved ones with neurological and mental health conditions.
This event brings together healthcare professionals, research advocates and community members to provide education, support and access to valuable resources.
Attendees will learn about local services, caregiver support tools and clinical research opportunities that help advance new treatments while expanding care options for loved ones.
The featured speaker is Dr. William Justiz, a board-certified neurologist with a focus on Alzheimer’s disease, dementia and cognitive decline. Dr. Justiz earned his Bachelor’s degree in Biological Science from Northwestern University and his medical degree from the University of Miami.
The community event is scheduled from 12 p.m. until 1 p.m. at Baker Senior Center Naples, 6200 Autumn Oaks Lane. The cost is $10 per person.
Scholarships are available to assist with the fee. Seats are limited and registration is required. For more information or reservations, contact Kelley Findlay at 239-325-4444.
The Collier Children’s Advocacy Center brought together community members for a focused discussion on the importance of trauma-informed response during its “From Surviving to Saving Lives” event in March at Gulfshore Playhouse.
Held in partnership with the Naples Children’s Foundation, the program “reinforced how coordinated, trauma-informed care supports a child’s path to recovery.”
Tonier Cain, a childhood abuse survivor and nationally recognized advocate, shared her journey and the role trauma-informed care played in her healing.
Lt. Wade Williams of the Collier County Sheriff’s Office provided insight into a local case involving suspected child abuse, illustrating how trauma-informed practices can strengthen investigations.
“Our goal to provide trauma-informed care to children across Collier County depends on a community that is informed and engaged,” said Jackie Stephens, CEO of Collier CAC. “These conversations give the community insight into how they can help children in their neighborhoods receive the support they need during difficult times.”
The event also included recognition of Collier CAC’s “Seeds of Strength” recipients, honoring individuals whose support has advanced the organization’s mission. Honorees included board member Brad Boaz, Julie Van Tongeren of the Collier Community Foundation, Lise Eichenlaub, daughter of longtime supporter Daphne Pfaff and Sarah Zaiser-Kelly of the Naples Children Foundation.
More: Now You Know: Pole Vault in the Plaza; Fire Station 31 ceremony
And: Now You Know: New projects for Estero; Wonder Gardens CEO to retire
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Ingka Investments, as a part of its INR 10 billion (EUR 97.5 million) renewable energy commitment to India, launches a 210 MWp solar installation in Bikaner, Rajasthan, making it the company’s first renewable investment in the country.
Ingka Investments, the investment arm of Ingka Group, the largest IKEA retailer, has made a 100% stake investment in a subsidy-free 210 MWp solar project located in Rajasthan, India. The solar project has reached ready-to-build status, and construction will start shortly. Start of operations is scheduled in December 2026. The total expected production is 380 GWh per year.
Frederik de Jong, Head of Renewable Energy at Ingka Investments, says: “This is a milestone acquisition for us – it marks the first renewable energy investment for Ingka Investments in India – a country of utmost importance both for IKEA retail and the IKEA supply chain. The new solar project in India will produce 380 GWh of renewable energy annually – more than enough to power our growing retail, shopping centre, and distribution operations. It’s a big step in making our retail business in India more sustainable, efficient, and future-ready.”
The investment is part of the EUR 7.5 billion the company has committed to supporting 100 percent renewable energy consumption across the value chain and beyond by 2030.  Ingka Investments has so far invested and committed EUR 4.2 billion into renewable energy projects in wind and solar energy worldwide.
In India, the company is working with ib vogt, an integrated large-scale solar PV developer headquartered in Germany with a strong presence in India. ib vogt Solar India will also be the partner for construction, and the first three years of operations. The construction and operations of the solar project will provide significant local employment, estimated to be around 450 people during construction and 10 to 15 during operations.
Patrik Antoni, CEO, IKEA India, shared, “At IKEA, sustainability is at the heart of everything we do. Over the past eight years, we’ve invested in making our retail journey more sustainable. Designed with energy efficiency at the core, two of our large-format stores in Bangalore and Navi Mumbai are LEED Gold certified, and we are working towards Platinum certification in Gurugram and Noida. As a founding member of RE100, we are on track to power our operations with 100% renewable energy by 2025. We’re also proud of our 100% zero-emission EV deliveries in key cities and are committed to expanding this across all future markets. With EV charging stations in our stores and energy-saving solutions for our customers, and now also an investment in a solar project, we’re inspiring positive change and contributing to a cleaner, more sustainable future for India.”
As a global business operating in 31 countries, Ingka Group is committed to the Paris Agreement and to contribute to limiting the global temperature rise to 1.5°C. In November 2023, the company strengthened its climate targets in alignment with the Science Based Targets initiative (SBTi) Corporate Net-Zero Standard.
The targets were approved by SBTi in April 2024 and include a commitment to reduce absolute greenhouse gas emissions from the value chain by at least 50% by FY30 (compared to FY16 baseline) and reach net zero emissions by 2050, without relying on carbon offsets to meet these absolute reduction targets.
 
About Ingka Investments
Ingka Investments is the investment arm of Ingka Group, the largest IKEA retailer. They invest in assets, manage companies, and operate strategic businesses to preserve and create value for Ingka Group and IKEA – now, and for generations to come. Taking a long-term approach, they responsibly invest across six strategic areas: forestland, renewable energy, real estate, circular, financial markets, and business acquisitions and venture investments. Ingka Investments has committed to invest EUR 7.5 billion by 2030 into utility-scale wind and solar projects to increase production of renewable energy as well as investing in technologies to support the energy transition, from storage solutions to charging stations.
Further information on Ingka Investments: https://www.ingka.com/what-we-do/ingka-investments/
About Ingka Group 
With IKEA retail operations in 31 markets, Ingka Group is the largest IKEA retailer and represents 87% of IKEA retail sales. It is a strategic partner to develop and innovate the IKEA business and help define common IKEA strategies. Ingka Group owns and operates IKEA sales channels under franchise agreements with Inter IKEA Systems B.V. It has three business areas: IKEA Retail, Ingka Investments and Ingka Centres. Read more on Ingka.com. 
For further information, journalists and media professionals can contact us at [email protected] or by calling +46 70 993 6376. 
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Patrik Antoni, CEO, IKEA India
Meeting with the Union Minister of State for Environment, Mr Kirti Vardhan Singh
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A long-promised project to shift Stewart Island to solar power could be underway within months and operational by Christmas, officials say.
Rakiura’s 480 residents currently rely entirely on diesel for power generation, and are bracing for a steep rise in prices due to the conflict in the Middle East.
Southland Mayor Rob Scott said officials were looking at ways to speed up progress on the planned solar farm, which secured a $15 million government loan last year.
Stewart Island Rakiura is fully reliant on diesel to keep the power on. Photo: RNZ / Mark Papalii
The council was about to apply for consent and, under the Resource Management Act (RMA), was seeking to classify the project as emergency works to be carried out in exceptional circumstances, he said.
“This is certainly an exceptional circumstance … so we’re currently exploring Section 330 of the RMA, which would enable us to get started while going through the consenting process,” he said.
The aim was to begin construction in June, and it could not happen soon enough, as far as Scott was concerned.
The solar farm would reduce diesel consumption for electricity by about 75 percent, he said.
“I guess the project’s kind of proven its value now. One of the reasons why we’ve done it is not just to address the high power prices that residents on the island were already paying, but to take out some of this vulnerability, the susceptibility to high diesel prices which we’re experiencing right now,” he said.
Sharon Ross Photo: RNZ / Mark Papalii
Long time resident Sharon Ross said she was setting aside cash in preparation for this winter’s power price hikes – and she dreaded finding out just how much of an impact global fuel price surges would have.
In a normal year, her household spent between $500 – $800 per month on electricity, she said.
Ross, who is also the co-owner of the island’s only petrol station, said fuel at the pump had gone well over the $4-a-litre mark.
“We are expecting this winter is going to be a lot harder than other winters have been for us,” she said.
Southland District councillor Jon Spraggon. Photo: RNZ / Mark Papalii
Southland District councillor Jon Spraggon, from the Rakiura ward, said the council-owned power station had issued a warning to residents to conserve electricity where they could.
“It’s worth noting the price of diesel for the council for the power supply went up 45 percent in the last week, so that’s going to have to be passed on somehow,” he said.
There were limitations on how quickly the council could raise the price, but residents could expect a few “short steps” up in their power bills, he said.
“There’s no way we can hold the power price down, and people are going to have to look at the amount of power that they actually use.”
Fuel at the pump has gone well over the $4-a-litre mark. Photo: RNZ / Mark Papalii
Spraggon said he was optimistic the solar farm could be running by Christmas.
“The community board chair and I are spending a lot of time trying to get this through as fast as we can,” he said.
Local business owner Helen Cave said the power bills for her hotel and fish processing business were already more than $10,000 a month each.
Local business owner Helen Cave. Photo: RNZ / Mark Papalii
The potential for further price hikes this winter had prompted her to explore alternatives, she said.
“I’d rather pay more than not have it, but I have ordered some solar panels,” she said.
Resident Morgan Bellworthy Hamilton said he, too, was looking at ways to reduce his own reliance on the grid, even with the promise of an island-wide transition.
“We’ve been talking about solar, and I think it probably is the best option for us, as a house, to get solar,” he said.
Resident Morgan Bellworthy Hamilton. Photo: RNZ / Mark Papalii
Snuggery Café co-owner Simon Moir, who used solar to offset his power bill by about 30 percent, said he was excited for the whole-island upgrade but wary it would not be a silver bullet.
Rakiura’s climate made it a difficult place to rely on the sun for electricity, he said.
“I’m pretty excited for it, but I don’t know how much it’s actually going to fully cover and what sort of price reduction that will truly create … we don’t have a lot of sunshine here just because of where we’re positioned in the world, and we get a lot of cloudy days,” he said.
“But I’m really grateful that our Southland mayor has finally taken the true steps to get it across the line and get the money from the government to pursue this.”
Snuggery Café co-owner Simon Moir. Photo: RNZ / Mark Papalii
Stewart Island’s solar project follows a mooted hydro scheme and a failed wind farm.
Ross said when it came to switching the island off diesel, there had been years of false starts.
“When we moved here 14 years ago, we seemed to be in the exact same conversation. And they kept on doing studies, and they would revisit these studies, and nothing happened. And we’re thinking, if this is the third, well, probably fourth time that it’s been reviewed, and nothing is going to come of it again, it would be so incredibly frustrating,” she said.
Photo: RNZ / Mark Papalii
Scott said while there were still hurdles to work through, residents could be assured that this time was different.
“I don’t accept failure and I’ve given the island my word that this project’s going to go ahead,” he said.
The volatility of global oil markets was another reason to make the project happen as soon as possible, he said.
The solar farm would not bring prices down to mainland levels, but would help lower bills and make them more predictable, he said.
“We do need to factor in the maintenance and the replacement of the solar farm. So the prices are still going to be relatively high, but they are going to be certain and stable,” he said.
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Rakiura relies on diesel generators for electricity, burning through about 1000 litres of diesel a day to create power. Audio
The government is providing $15 million for a solar farm on Stewart Island with the hope of reducing steep power prices.
Contact Energy said it was an important project to support energy security of supply for all New Zealanders.
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A $500 million commercial-scale Converse County solar project has been delayed because the company doesn't have a buyer for its power. “We know the project isn’t real until they break ground,” said state Sen, Brian Boner, adding he’s not surprised.
April 08, 20265 min read
A $500 million solar project expected to bring $157 million in property tax revenue to Converse County is delayed as the company behind the project continues to seek a buyer for the power it would produce.
Donald Millar, the senior director of development at BrightNight LLC met with Converse County Commissioners on Tuesday to announce the delay of its project, which calls for building the solar panels high enough for sheep to graze under them.
The Dutchman Renewable Power Project was expected to start construction in June, Commissioner Rick Grant told Cowboy State Daily.
But because the company has still not determined how to connect the power it will generate to the grid and who that power will serve, construction is now not expected until sometime in 2027, he said.
That’s after the project was initially scheduled to begin construction in March 2024 and come online in July 2026.
“They’re waiting on a good, firm commitment,” Grant said.
The Dutchman project will be Converse County’s first commercial-scale solar project.
State Sen. Brian Boner, R-Douglas, said he’s not surprised by the announcement.
“We know the project isn’t real until they break ground,” he said.
Calls and emails to BrightNight were not returned prior to publication.
The Dutchman development is not the first solar project in Wyoming to stall because it doesn’t yet have a buyer for its electricity.
A solar project in Goshen County that aimed to produce 163 megawatts of electricity hit a big snag last year when it was ready to develop but had no feasible way of transmitting the electricity it would generate to market.
Cowboy Energy of Sheridan had invested millions of dollars and spent three years developing what would be one of the state’s first agriculture-friendly solar installations in Goshen County. The company lost its investment partner, Portugal-based Greenvolt Power, because it couldn’t find a buyer for the power.
The project would also have generated needed economic benefits for the second poorest county per capita in Wyoming, Brian Young, CEO of Go Goshen Economic Development, previously told Cowboy State Daily. 
“That would be a game changer in terms of our county and municipal tax generation,” he said.
Wyoming’s first commercial-scale solar power facility, with more than 1.2 million solar panels, became operational in April 2024. 
The power generated by the $1.2 billion South Cheyenne Solar Facility is being sold under a purchase agreement with Cheyenne Light, Fuel and Power, a subsidiary of Black Hills Energy.
That’s according to Qcells, a renewable energy company and one of the top manufacturer of solar panels in the U.S. 
The power from that solar farm exclusively provides renewable energy to the Cheyenne Microsoft data center.
Boner said his county is familiar with all types of energy projects. 
He expressed little surprise upon learning what was to be Wyoming’s third commercial-scale solar power plant is being delayed. 
A delay in the project’s start also means a delay in tax dollars for the county as well as in added jobs.
“You’re stuck with a lot of variables that are completely outside of your control,” Boner said, variables that would be beneficial to local family businesses.
“Any sort of energy project will make our agriculture more sustainable and will help keep ranches in the family,” Boner said.
Grant said BrightNight is still in talks with two of Wyoming’s major power suppliers, Rocky Mountain Power and Black Hills Energy, about possible purchasing agreements for electricity the Dutchman project would produce.
Boner speculated whether part of the hang-up is because Rocky Mountain Power is going through a transitional period.
“There’s been some turbulence within Rocky Mountain Power,” he said. “They’re dealing with a lot of change within their organization.”
Jona Whitesides, a spokesman for Rocky Mountain Power, said the company does buy electricity from a few solar facilities in Wyoming. 
He declined to say whether Rocky Mountain Power has been approached by BrightNight about buying the electricity it will generate, citing confidentiality agreements between parties.
Boner also postulated that lack of certainty around energy tax credits could be driving the hesitation of potential buyers of solar power.
“We have to be serious about baseload power,” he said, referring to power generated by coal, natural gas and nuclear. “The fact is, we haven’t kept up with building those power resources.”
Wyoming generates about 15 times more energy than it consumes. Much of that power has to travel long distances to where it’s is actually needed. 
Initially, BrightNight LLC was one of two developers named for the Dutchman solar project. 
The other, Canada-based Cordelio Power, was recently acquired by Pattern Energy. 
It’s not clear whether Pattern Energy will have a stake in the Dutchman project or whether the project is now BrightNight’s alone. 
Cowboy State Daily reached out to Pattern Energy for comment but had not received a response prior to publication.
Kate Meadows can be reached at kate@cowboystatedaily.com.
David Madison6 min read
Dale Killingbeck6 min read
Kate Meadows is a writer for Cowboy State Daily.
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Clair McFarlandApril 08, 2026
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Source: Xinhua
Editor: huaxia
2026-04-08 19:50:00

A ceremony marking the operation of a 1,000-MW photovoltaic project developed by China General Nuclear Power Group (CGNPC) is held in Vientiane, Laos, April 7, 2026.(Photo by Kaikeo Saiyasane/Xinhua)
SHENZHEN, April 8 (Xinhua) — A 1,000-MW photovoltaic project in Laos was connected to the power grid and entered operation on Tuesday, developer China General Nuclear Power Group (CGNPC) announced.
Located in Oudomxay province, the large-scale solar farm is expected to generate 1.65 billion kWh of electricity annually and reduce carbon dioxide emissions by approximately 1.3 million tonnes per year.
As one of the major solar installations in Laos, located in a mountainous region, the project created nearly 3,000 local jobs at the peak of construction. It also contributed to local infrastructure by repairing roads and reinforcing five bridges, delivering tangible economic and social benefits to the surrounding communities.
On the industrial cooperation front, the project brought together more than 70 enterprises from both China and Laos — including over 30 Laotian companies involved in construction, equipment supply and raw materials.
CGNPC also supported the establishment of a clean energy power standards research institute in Laos and trained nearly 100 local engineers. Environmental protection measures, such as avoiding construction in sensitive areas and implementing ecological restoration, were adopted to help preserve the natural landscape.
Yang Changli, chairman of CGNPC, said the company will accelerate the development of clean energy projects in Laos, contributing to a closer China-Laos community of shared future through green energy cooperation. ■

An aerial drone photo taken on Dec. 29, 2025 shows a 1,000-MW photovoltaic project developed by China General Nuclear Power Group (CGNPC) in Oudomxay province, Laos.(CGNPC/Handout via Xinhua)

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China powers up major Southeast Asian solar project amid Iran war shock  South China Morning Post
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Plans have been submitted for the installation of 1,200 solar panels on the roof of the Isle of Man's National Sports Centre (NSC).
The move forms part of wider plans by Manx Utilities to generate 75% of the island's electricity through solar and onshore wind projects, backed by the government in early 2023.
If the plans are approved, the solar panels on the NSC in Douglas would have a capacity to generate 735 kW of electricity, enough to power hundreds of homes.
Manx Utilities said it formed part of a wider programme "to support the island's transition to cleaner energy, reduce reliance on imported electricity and deliver practical early renewable generation at public buildings".
The submission follows "detailed structural and technical assessments of the NSC roof to ensure the installation meets all safety, design and performance requirements," a Manx Utilities spokesperson said.
A certificate of lawful development, which does not require planning approval, has also been submitted in case the plans are not given the go-ahead, which would see the solar panels generate less electricity at 650 kW.
Manx Utilities said that via either route, the plans would progress, however it was preferred that the proposals were approved as it would allow for more electricity to be generated.
Further updates would be provided as the application progressed through the planning process, it continued.
The plans form part of a wider island strategy to generate 10 MW of solar energy.
Manx Utilities is also in the process of exploring options for installing ground-mounted solar panels in Balladoole, Ramsey, and a floating solar array in Sulby Reservoir.
Read more stories from the Isle of Man on the BBC, watch BBC North West Tonight on BBC iPlayer and follow BBC Isle of Man on Facebook and X.
Smile Dental says a temporary location provided by Manx Care during hospital works is "unsuitable".
The route is closed until 15:30 BST on17 April while preparation works for the TT take place.
An event to showcase Science, Technology, Engineering and Maths careers was recently held.
Some Manxman sailings this week were rescheduled due to insufficient water depth.
Enthusiasts share their stories as the island's railway celebrates the start of its 150th season.
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Spark Renewables has secured final state planning approval for a solar and battery project that will add 800 MW of PV and 356 MW / 1,574 MW of energy storage capacity to the grid in the New South Wales Riverina region.
Image: Spark Renewables
The New South Wales (NSW) Independent Planning Commission (IPC) has granted approval for the Dinawan Solar Farm and battery project being developed by Spark Renewables near Coleambally in the state’s southwest.
Spark, owned by Malaysian electricity giant Tenaga Nasional Bhd (TNB), said the Dinawan project combines an 800 MW solar installation comprising about two million solar panels with a 356 MW / 1,574 MWh battery energy storage system.
The developer said the hybrid project, which sits within the South West Renewable Energy Zone (REZ), will deliver large-scale dispatchable renewable power to Australia’s grid, contributing to “improving grid stability and energy security, while reducing reliance on fossil fuel-based generation.”
The $1.35 billion (USD 930 million) solar farm and battery project was recommended for approval by the Department of Planning, Housing and Infrastructure in December but referred to the IPC for determination after more than 50 public objections were made during its assessment period.
The IPC has now approved the project after considering concerns raised relating to cumulative impacts, traffic and roads, noise, contamination, social impacts, emergency planning, local infrastructure and insurances.
In its statement of reasons, the Commission said the project would assist in “improving grid stability and energy security” and aligns with NSW government commitments to transition to renewable energy.
The project is also expected to create approximately 400 full-time jobs during construction and once operational will generate enough renewable energy to power approximately 142,000 homes.
The IPC has imposed some conditions of consent to minimise the potential adverse impacts from the project, including requiring Spark to implement a traffic management plan, noise management protocols and fire safety study and emergency plan.
Spark Chief Executive Officer Anthony Marriner said the approval of the solar and battery is a major step forward for the planned Dinawan Energy Hub, a complex that is to also include a 1.2 GW wind farm.
“With the solar farm now approved, we look forward to the upcoming determination of the Dinawan Wind Farm and progressing the full Dinawan Energy Hub toward delivery.”
The approval of the solar and battery project comes as new research suggests Spark is set to become an increasingly important lever for TNB’s renewable energy expansion outside Malaysia, while also serving as a critical learning platform to support that country’s net-zero 2050 ambitions.
Malaysia-based Hong Leong Investment Bank Research (HLIB Research) said Spark’s current contribution to TNB’s overall operation is minimal, as its only operational asset is the 100 MW Bomen Solar Farm, but noted that the growth pipeline is substantial.
Spark, acquired by TNB in 2023, is currently developing more than 3 GW of solar, wind, and battery storage projects across the National Electricity Market, including the Mallee solar, wind and battery energy hub, and the 615 MW Wattle Creek solar and battery project, both in NSW.
HLIB Research said beyond asset expansion, Spark also offers TNB exposure to more advanced electricity market structures, adding that insights gained in Australia could be applied to Malaysia’s own energy transition.
“The platform allows TNB to understand renewable energy implementation and power sector structures in more advanced countries,” it said.
The research house said TNB is also leveraging Spark for talent development and knowledge transfer, with staff secondments supporting capability building in renewable energy technologies, financing structures and regulatory frameworks.
TNB, the largest listed energy utility company in Southeast Asia with a market capitalisation of about $28 billion, is targeting the installation of 14.3 GW of renewable energy capacity globally by 2050.
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Aggreko And Harmony Gold Partner To Build Australia’s Largest Off-Grid Renewable Hybrid Power Facility  SolarQuarter
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MyChesCo
Chester County News and Community Website
MALVERN, PA — Vishay Intertechnology Inc. (NYSE: VSH) introduced a new automotive-grade photovoltaic MOSFET driver designed for high-voltage vehicle applications.
The device, designated VODA1275, is the first of its kind in the SMD-4 package to provide an 8 mm creepage distance and a mold compound with a comparative tracking index of 600, according to the company.
Vishay said the driver is designed to improve safety and reliability in high-voltage automotive systems while reducing design complexity and cost.
The device delivers a typical open circuit voltage of 20 volts, short circuit current of 20 microamps, and a turn-on time of 80 microseconds, enabling faster switching performance in systems using MOSFETs and insulated-gate bipolar transistors.
The VODA1275 is rated for a working isolation voltage of 1260 volts peak and an isolation test voltage of 5300 volts RMS, making it suitable for battery systems exceeding 800 volts.
The company said the driver is AEC-Q102 qualified and intended for use in pre-charge circuits, wall chargers, and battery management systems in electric and hybrid vehicles.
The device’s higher output voltage allows designers to use a single driver instead of multiple components in series, which can reduce system size and cost, according to the company.
The optically isolated driver operates using an internal infrared emitter, eliminating the need for an external power supply.
Vishay said the product is compliant with RoHS standards and is halogen-free.
For the latest news on everything happening in Chester County and the surrounding area, be sure to follow MyChesCo on Google News and MSN.
 
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Brazil’s National Electric Energy Agency (Aneel) has signed the country’s first-ever authorization for a co-located battery energy storage system (BESS) tied to a solar generation facility, marking a significant regulatory milestone for the Brazilian energy storage market.
The system is linked to the Sol de Brotas 7 photovoltaic plant, owned by Statkraft, in the municipality of Uibaí, Bahia. The Sol de Brotas complex is also authorized to share transmission infrastructure with the Ventos de Santa Eugênia wind complex.
The lithium-ion BESS has a nominal capacity of 5 MWh and a total installed power output of 1.25 MW. The conversion system is rated at 2.3 MW, with an inverter output voltage of 0.60 kV, physically integrated into the solar plant’s existing infrastructure. By sharing grid connection facilities with the host generation asset, the system will store surplus energy and dispatch it to the grid on demand.
The colocated storage system may consume energy from both the Sol de Brotas 7 photovoltaic plant itself and the grid to which it is connected, but consumption through direct connection to other generating plants in the complex is prohibited. The storage system will operate by sharing the plant’s metering and billing systems, under the terms applicable to colocated storage systems.
“Batteries offer a medium- and short-term solution to a problem that will intensify over time. The expansion already signals very vigorous growth in renewables in Brazil in the coming years, so we need a regulatory framework that provides security for investors and also allows the development of a supply chain that enables the electrical system to continue delivering good performance results,” said the Director-General of Aneel, Sandoval Feitosa, during the authorization signing ceremony.
The event was attended by the director of Aneel, Agnes da Costa, the agency’s technical team, and representatives from the Brazilian Photovoltaic Solar Energy Association (Absolar), the Brazilian Wind Energy Association (Abeeólica), and the Brazilian Association of Energy Storage Solutions (Absae).
In October 2025, Aneel published specific guidelines for entrepreneurs interested in installing co-located storage systems in already licensed generating plants.
From pv magazine Brazil.
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New solar marketplace opening to provide advice, options for consumers
New solar marketplace opening to provide advice, options for consumers
New solar marketplace opening to provide advice, options for consumers
KMBC 9 News continues to investigate solar panel scams in Kansas City, where homeowners have paid thousands of dollars for systems that fail to work or companies that disappear.
Corey McDonald, who runs MC Solar KC and has decades of experience in Kansas City’s solar industry, has developed a new online marketplace that he believes will protect consumers.
The site will offer free advice to solar consumers, allowing them to choose solar installers and financing companies McDonald vets. It will also allow people to use artificial intelligence to design solar panel systems on their homes, without high-pressure sales tactics.
“People are being taken advantage of,” McDonald said. “That’s not cool.”
KMBC has spoken with dozens of people affected by solar scams, many of whom are stuck paying loans worth tens of thousands of dollars for systems that don’t work as promised.
“There are good companies,” he said. “There are reputable companies who would like to earn your business, not steal your business.”
Missouri Attorney General Catherine Hanaway has also taken notice of KMBC’s investigation.
KMBC has referred victims of costly solar loans to her office, and she is working to hold solar companies accountable.
“When we can get recovery for an actual human being and make their life just a little bit better, that that’s a great day around here,” Hanaway said.
One of the most important steps is to file a formal complaint with the Missouri Attorney General’s Consumer Protection Division. These complaints help investigators identify patterns and can lead to enforcement action.
You can file a complaint online here.
And for those still considering solar systems: “My hope is that I can provide a platform that can help a homeowner make a better decision,” McDonald said.
If you have a solar loan you are struggling to pay, email investigates@kmbc.com.
Hearst Television participates in various affiliate marketing programs, which means we may get paid commissions on editorially chosen products purchased through our links to retailer sites.

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IPPs Zelestra, BNZ and ALFI have secured offtake and financing to hybridise solar projects with BESS across Spain, Italy, Portugal and Romania. 
Independent power producer (IPP) Zelestra has signed a solar-and-storage power purchase agreement (PPA) with power firm EDP that will enable the addition of a battery energy storage system (BESS) to its operational 50MW Pizarroso solar plant in Cáceres, Spain.
It will add a 160MWh BESS to the PV plant which has been online since 2023. EDP is already the offtaker of the solar plant, and will use the BESS to enhance energy management and system flexibility.
Zelestra said it is the first PPA that enables the hybridisation of a solar PV plant with BESS in Spain. The two companies signed a solar-and-storage PPA in 2025, also claimed as the first of its kind, but for that both the solar and BESS were greenfield.
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Zelestra’s chief product officer Stefano Breda subsequently discussed that PPA with ESN Premium, calling it ‘PPA 2.0’.
It is part of a wider industry move away from solar-only PPAs towards hybridisation, because of falling PPA prices due to high curtailment and price cannibalisation. BESS enables solar PV plant operators to shift that production into the later evening and night hours, as well as provide services to the grid that solar PV would struggle to, like ancillary services and capacity markets (CM).
BNZ, an IPP owned by investor Nuveen Infrastructure, has revealed plans to add 850MW of BESS capacity to its solar PV portfolio across Spain, Italy and Portugal. It is part of a move to energy management and hybridisation being ‘at the core of its business’, the firm said.
The company will initially deploy 530MW of BESS (duration not disclosed) across the three countries in 2026 and 2027. 260MW of that will be in Spain, 210MW in Italy and 60MW in Portugal.
Luis Selva, CEO of BNZ, said the shift in strategy will enable it to “…apply advanced energy management to transcend the role of a traditional developer and consolidate our position as a comprehensive strategic partner, capable of managing energy intelligently to optimise the performance and flexibility of our entire infrastructure”.
BNZ is new to storage but our colleagues at PV Tech have covered its solar PV activity extensively.
Nuveen managing director Isabel Rodriguez de Rivera recently discussed BESS bankability in Southern Europe with Energy-Storage.news, while her colleague Pierre Bartholin, head of power hedging, said that ‘standalone solar is not dead, but it is challenging’ at our publisher Solar Media’s Solar Finance Investment Europe 2026 in February.
In related news, investor Alfi Green Energy Fund and developer Kraftfeld Energy have closed a transaction to establish a 65:35% JV entity that is developing a 126MW solar, 200MWh BESS project in Romania. Construction is underway for commercial operations at the start of 2027.

The two companies have already secured project financing of €90 million (US$105 million) with Raiffeisen Bank International AG acting as agent.
Romania has quickly become one of the most active large-scale BESS markets in Europe, as recently covered by Energy-Storage.news. We’ve recently interviewed three IPPs building BESS in Romania for ESN Premium articles: MetaWealth, Econergy and R.Power (the latter two are video interviews taped at the Energy Storage Summit 2026 in February).

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The development of molecule-based selective contacts has boosted the power conversion efficiencies of inverted perovskite solar cells. However, these molecular films, often assembled as monolayer or multiple layers on the substrate, are prone to molecular desorption and structural deformation, limiting the long-term stability of devices. This instability, in essence, originates from the weak contacting structure between the transparent conductive oxide and molecular layer, with a limited interface offering insufficient adhering forces to immobilize the molecules. A general architectural strategy that circumvents this fundamental limitation without compromising electronic functionality is highly demanded, but remains underexplored. We now report a universal architecture of a bulk nano-heterointerface that reconstructed the molecule-based selective layer. The substantially increased chemical interface and strengthened binding force between the molecules and rationally designed nanoscale scaffolds greatly improved the device operational stability, achieving high efficiency. The strategy proved versatile, successfully applied to various molecular systems to enhance device performances, and remained effective in upscaled devices produced via scalable blade coating.
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We thank L. Liu, Y. Nie and Z. Yang from the Instrumentation and Service Center for Physical Sciences (ISCPS) and X. Lu, Y. Chen, Z. Chen and Y. Cheng from the Instrumentation and Service Center for Molecular Sciences at Westlake University for assistance in characterizations. J. Xue acknowledges support from the Natural Science Foundation of Zhejiang Province of China (grant numbers LR24F040001 and DG25E020001), the National Natural Science Foundation of China (grant number 62274146), the Scientific Research Innovation Capability Support Project for Young Faculty (SRICSPYF-ZY2025093), the Central Guidance Funds for Local Science and Technology Development Projects (grant number 2025ZY01012) and the Fundamental Research Funds for the Central Universities. Y.L. acknowledges support from the National Natural Science Foundation of China (grant number 625B2166). Y.T. acknowledges a grant from the National Natural Science Foundation of China (grant number 624B2117). R.W. acknowledges grants from the National Natural Science Foundation of China (grant number 62474143) and Natural Science Foundation of Zhejiang Province of China (grant numbers LD24E020001 and QKWL25E1301), support from the Key R&D Program of Zhejiang (grant number 2024SSYS0061), Zhejiang Key Laboratory of Low-Carbon Intelligent Synthetic Biology (2024ZY01025), Muyuan Laboratory (programme ID 14136022401) and support from the Scientific Research Innovation Capability Support Project for Young Faculty (grant number SRICSPYF-BS2025014). H.-f.W. acknowledges the National Key Instrumentation Development grant by the National Natural Science Foundation of China (grant number 21727802).
These authors contributed equally: Yixin Luo, Jiahui Shen.
State Key Laboratory of Silicon and Advanced Semiconductor Materials, School of Materials Science and Engineering, Zhejiang University, Hangzhou, China
Yixin Luo, Jiahui Shen, Ke Zhao, Yuan Tian, Lu Jin, Xuechun Sun, Qinggui Li, Runda Li, Hengyu Zhang, Haimeng Xin, Jiazhe Xu, Donger Jin, Zhenyi Ni, Deren Yang & Jingjing Xue
Department of Materials Science and Engineering, School of Engineering, Westlake University, Hangzhou, China
Jiahui Shen, Ke Zhao, Shenglong Chu, Yuan Tian, Lu Jin, Xuechun Sun, Libing Yao, Qingqing Liu, Jiazhe Xu, Jingjing Zhou & Rui Wang
School of Chemistry and Materials, Yangzhou University, Yangzhou, China
Jiahui Shen & Ruzhang Liu
Shangyu Institute of Semiconductor Materials, Shaoxing, China
Ke Zhao & Jingjing Xue
Department of Physics, Marmara University, Istanbul, Turkey
Caner Değer & Ilhan Yavuz
Department of Chemistry, Zhejiang University, Hangzhou, China
Bo-jun Zhao, Li Zhang & Hong-fei Wang
Department of Chemistry, Westlake University, Hangzhou, China
Bo-jun Zhao & Li Zhang
Zhejiang Key Laboratory of Precise Synthesis of Functional Molecules, Instrumentation and Service Center for Molecular Sciences and Research Center for Industries of the Future, Westlake University, Hangzhou, China
Xiaohe Miao
Department of Nano Engineering, Department of Nano Science and Technology, SKKU Advanced Institute of Nanotechnology (SAINT), Sungkyunkwan University (SKKU), Suwon, Republic of Korea
Seung-Gu Choi
Department of Energy Systems Engineering, College of Engineering, Seoul National University, Seoul, Republic of Korea
Jin-Wook Lee
School of Transdisciplinary Innovations, Seoul National University, Seoul, Republic of Korea
Jin-Wook Lee
Department of Chemistry, Korea University, Seoul, Republic of Korea
Hyo Jae Yoon
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J. Xue conceived the idea and supervised the project. Y.L. and J.S. performed the experiments and data analysis under the supervision of J. Xue. K.Z., S.C. and L.J. fabricated the solar cell devices. B.-j.Z. and L.Z. performed the SFG-VS measurements under the supervision of H.-f.W. C.D. and I.Y. conducted the theoretical calculations. Q. Liu synthesized the molecules. Y.T., X.S., L.Y., X.M., Q. Li, R. Li, H.X., J. Xu, J.Z. and D.J. assisted with the characterizations and device fabrication. S.-G.C. performed the cross-sectional KPFM under the supervision of J.-W.L. H.Z. performed the cross-sectional TRPL mapping under the supervision of Z.N. R. Liu, R.W., H.J.Y. and D.Y. provided helpful discussions. J. Xue wrote the paper. All authors discussed the results and commented on the paper.
Correspondence to Jingjing Xue.
The authors declare no competing interests.
Nature Materials thanks the anonymous reviewers for their contribution to the peer review of this work.
Publisher’s note Springer Nature remains neutral with regard to jurisdictional claims in published maps and institutional affiliations.
Supplementary Notes 1–10, Figs. 1–130, and Tables 1 and 2.
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Luo, Y., Shen, J., Zhao, K. et al. Bulk nano-heterointerface secures molecular contacts in perovskite solar cells. Nat. Mater. (2026). https://doi.org/10.1038/s41563-026-02546-1
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DOI: https://doi.org/10.1038/s41563-026-02546-1
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by Maxwell Valva
ANDERSON, Calif. — The city of Anderson has completed a 757-kilowatt solar array project at its wastewater treatment plant. The panels, installed by Schneider Electric, are expected to generate more than $7.5 million in guaranteed energy savings over the next 20 years.
“Our wastewater treatment plant is one of the most energy-intensive facilities we operate. With rising energy costs, it became clear we needed smarter, more sustainable solutions,” said Adam Whelen, the city’s public works director.
The city has obtained grandfathered status under PG&E’s Net Energy Metering 2.0 program, ensuring favorable solar credit rates for years to come.

A look at the newly installed solar array in Anderson at its wastewater treatment plan, April 8, 2026{ } (City of Anderson)

“This project was a priority for our community. It will save Anderson residents money for decades and beyond,” said Joey Forseth-Deshais, city manager.
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by TAMARA SACHARCZYK, NBC 10 NEWS
WARWICK, R.I. (WJAR) — Black mold filled the attic of Michael Pella-Sabourin's home after a roof leak went undetected for months.
"We're in the bathroom and there was a puddle of water on the floor," Pella-Sabourin said. "We ended up with black mold."
A contractor's report found the costly damage was caused by improperly installed solar panels.
"There are pictures of where they put nails in. They didn’t put any kind of silicone on it to block the water from coming in, and it's all across the entire stretch where the solar panels are," he said.

It's a story the NBC 10 I-Team has covered before, but now with a new development: Smart Green Solar, the company that installed the panels, has shut down.
"Come to find out all the numbers are disconnected," Pella-Sabourin said. "I contacted the Better Business Bureau, and they said that they had gone bankrupt."
His case comes as an I-Team investigation found at least a dozen solar companies in the region have closed over the past year, leaving some customers without answers or protections.
Like many solar agreements, Pella-Sabourin’s contract included a warranty for the panels and insurance coverage for installation issues — protections that may no longer apply if the company is out of business.
The Rhode Island Department of Business Regulation says it received 15 complaints over the past year related to solar companies closing. While companies must register with the state, regulators cannot require contingency plans for sudden shutdowns.
The I-Team tracked down Smart Green Solar owner Jay Gotra, who claims he's trying to help Pella-Sabourin file what would effectively be a retroactive insurance claim.
"This isn't a warranty issue. This is improper work that was performed," Gotra said. "We did more than 3,500 solar installations in Rhode Island. To say we were perfect would be far from the truth. But in situations like these, we were able to have our insurance policies cover these things."
Gotra said the now defunct company no longer carries insurance but believes a claim could be filed based on coverage at the time of the installation.
"We don't have insurance right now. This is because when the incident happened back in the day, we did have insurance policies at the time," he said.
He acknowledged that other homeowners in similar situations have limited options.
"Unfortunately, if more homeowners have this issue now, that is something you’d have to put through your insurance policy because we are not in business," Gotra said.
Asked whether bankruptcy allowed him to avoid responsibility, Gotra said, "No. I wish I could get off scot-free. I left with millions of dollars in loans."
Gotra blamed the company's closure on financial pressures tied to solar lending along with a state lawsuit filed by the Rhode Island Attorney General's office accusing his company of deceptive practices.
Bankruptcies among financing firms such as Solar Mosaic and Sunlight Financial have prompted the closure of solar companies across the country. Industry analysts say many solar lenders relied on capital markets and loan securitization, leaving them vulnerable when interest rates rose and demand weakened.
According to Solar Insure, more than 100 solar companies have closed since 2023.
"When banks start suffering, they pull back," Gotra said. "They don't care who goes under."
Gotra said customers still have 25-year warranties on their solar equipment, though they may be responsible for service costs.
Pella-Sabourin said he still has no guarantee the retroactive insurance claim will succeed and is calling for stronger consumer protections.
"The public is not informed of the consequences of this, that if these companies go out of business, it's all on you," he said.
The NBC 10 I-Team will continue to follow this story.
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ECA SA Warns Against Unqualified Solar Installations, Urges Strict Safety Compliance In South Africa  SolarQuarter
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Record high set on Monday and raised on Tuesday, with 14.4GW of electricity generated in sunny spring weather
Britain’s sunny spring weather powered the grid to new solar energy records on two consecutive days this week.
Solar farms in England, Wales and Scotland generated 14.1GW of low-carbon electricity at lunchtime on Monday, surpassing the previous high of 14GW in July last year.
And that record was toppled a day later when power generation from the sun’s energy climbed to another new high of 14.4GW on Tuesday afternoon.
The electricity system operator confirmed the new high as the government approved plans for the UK’s biggest solar farm to go ahead in Lincolnshire.
Ministers said the decision to support the Springwell solar farm in Lincolnshire built on their plan to “bring stability and lower bills in an uncertain world” by increasing homegrown low-carbon energy.
The project is expected to provide enough electricity to power the equivalent of 180,000 homes a year when generating at its maximum capacity.
The approval for Springwell comes six months after the government backed the Tillbridge solar farm, another super-sized facility in Lincolnshire, an area where Reform UK’s anti-renewables agenda has won rising support.
It is the 25th large-scale clean energy project approved by the Labour government since it came to power in 2024. Together, these could generate enough electricity to power the equivalent of up to 12.5m homes.
The solar record was confirmed less than a fortnight after Britain’s windfarms drove gas-fired power generation to a two-year low by reaching a record high.
Towards the end of last month, wind power climbed to a new high of 23.9GW, beating the previous record of 23.8GW set on 5 December, to generate the equivalent of enough electricity to power 23m homes.
At the time, gas-fired power was used to provide just 2.3% of the grid’s electricity, in a test of the government’s plan to run a virtually carbon-free grid by 2030. The electricity system operator is understood to be preparing to run the grid without any gas for short periods as soon as this summer, in a first for the UK energy system.
Michael Shanks, the energy minister, said: “We are driving further and faster for clean homegrown power that we control to protect the British people and bring down bills for good. It is crucial we learn the lessons of the conflict in the Middle East – solar is one of the cheapest forms of power available and is how we get off the rollercoaster of international fossil fuel markets and secure our own energy independence.”
The government has streamlined plans to bring “plug-in solar” to the UK, and updated building standards to require solar panels for new homes from 2028.

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Continued investment in renewable energy across SPAR country organisations  WebWire
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An international study found that the specific power of commercial silicon solar modules increased from 8.5 W/kg in the early 2000s to 23.6 W/kg today, driven by advances in module design, bifaciality, and temperature management. The researchers highlighted that glass and framing dominate module weight, and considering operating conditions like nominal operating cell temperature and rear-side illumination is essential for accurate PV system design.
Performance and physical parameter distributions of commercial crystalline silicon photovoltaic modules.
Image: UNSW, Cell Reports Physical Science, CC BY 4.0
From pv magazine Global
An international research team has found that the specific power of commercial silicon solar modules increased from around 8.5 W/kg In the early 2000s to 23.6 W/kg today.
The specific power of a PV module measures how much electrical power the module produces per unit of weigh. This metric can also be expressed in W/m2 and helps compare the efficiency of different solar panels regardless of their size or weight. It is especially important in space applications or portable solar panels, where weight matters more than area.
Their analysis also indicated that aluminum frames constitute 6%–19% of module weight, while encapsulants account for 2%–15%. Other components, including cells, junction boxes, backsheets, and interconnections, collectively contribute 8%–16% of the total weight. The researchers noted that while thinner glass or lighter frames can enhance specific power, such modifications may compromise mechanical reliability. Overall, they concluded that glass and framing are the principal factors governing module weight, efficiency, and handling challenges.
Their findings are available in the paper “Increasing specific power and the emergence of new markets for crystalline silicon photovoltaics,” published in Cell Reports Physical Science. The research group comprised scientists from the University of South New Wales (UNSW)  and the Newcastle Energy Centre in Australia, the Federal University of Santa Catarina (UFSC) in Brazil, the US Department of Energy’s National Laboratory of the Rockies, the University of Oxford in the United Kingdom. 
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Industrial sector companies, which provide foundational products for infrastructure and commerce, have experienced a favorable shift in regulatory conditions under the current administration. According to Yahoo Finance, this environment contributed to a sector gain of 4.7% over a recent six-month period, a time when the broader S&P 500 index declined by 2.3%.
Despite the sector’s recent performance, some individual companies show concerning financial trends. AAON, a manufacturer of HVAC equipment, has seen its operating margin decrease over a five-year span. Its earnings per share fell significantly on an annual basis over two years despite revenue growth, and its free cash flow margin also declined substantially during the five-year period. The company’s shares carry a forward price-to-earnings multiple of 40.8.
Shoals Technologies Group, which makes components for solar energy systems, reported annual sales declines over two years. Its earnings per share dropped at a rate greater than its revenue decrease during the same timeframe. The stock is valued at a forward P/E ratio of 16.5.
Novanta, a provider of technology for medical and manufacturing fields, posted revenue growth over two years that was below the industrial sector average. Its earnings per share growth during that period did not keep pace with its revenue increase, and its free cash flow margin contracted over five years.
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South Australia has opened up more than 11,000 square km of land for the potential development of renewable energy projects as it continues the march to its target of 100% net renewables by 2027.
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The South Australia government is calling for investors from around the globe to propose large-scale solar, wind, and storage projects across more than 11,000 square km of land released under the state’s renewable energy framework.
Applications are now open for renewable energy feasibility licenses covering the Whyalla West and Gawler Ranges East areas released under South Australia’s Hydrogen and Renewable Energy Act.
The Gawler Ranges East release area comprises approximately 5,200 square km on the Upper Eyre Peninsula, while the Whyalla West release area spans about 6,500 square km in the Upper Spencer Gulf region.
South Australia’s Department of Energy and Mining (DEM) said the two areas include some of the highest co-incident wind and solar resources in the state, with estimates suggesting they could host projects capable of powering more than 500,000 homes.
The DEM said the tender does not limit applicants to specific technology types, with investors invited to propose how they would optimize land use and renewable energy resources in the release areas.
“Tenders must address the prescribed criteria in their application, including how they plan to deliver the content within a timeframe, their experience, environmental management credentials, and how the project will benefit the state and the traditional custodians of the land,” it said.
The call for tenders in both areas is open until June 28, 2026, with the DEM saying the extended period allows applicants time to prepare bids and engage with native title holders on agreements.
South Australia is at the forefront of Australia’s clean energy transition, with the state currently averaging 75% net variable renewable energy annually and regularly achieving 100% instantaneous variable renewable energy generation, driven by large-scale wind and solar and rooftop PV. The state is targeting 100% net renewables by the end of 2027.
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Germany’s revised VDE standard enables simplified registration of larger plug-in photovoltaic systems and storage, removing previous capacity limits for self-installation.
Image: ready2plugin
From pv magazine Deutschland
A new German grid standard is opening the door to significantly larger plug-in PV systems that can be installed and registered without an electrician, according to industry participants.
The update to VDE-AR-N 4105:2026-03 introduces a simplified connection process for small generation systems with inverter output of up to 800 VA. Under the new rules, this process applies to PV systems above 2,000 Wp, systems with storage, or those seeking remuneration, allowing system operators to complete registration themselves using a dedicated form.
The revised framework removes formal limits on module capacity within this simplified process. However, the inverter output remains capped at 800 VA for plug-in systems, effectively defining their grid feed-in capacity.
In practice, developers can combine higher PV capacities with storage to optimize self-consumption. Industry estimates cited in the interview suggest systems of up to 10 kW could be configured under the new framework, although technical and regulatory thresholds apply. These include a requirement for smart meters for systems above 7 kW and compliance with product and installation standards such as DIN VDE V 0126-95 and DIN VDE V 0100-551-1.
The rules also clarify that plug-in systems without storage, below 2,000 Wp, and without remuneration requests can be registered solely in Germany’s market master data register, without notification to the grid operator. Larger systems or those with storage must still be registered with the grid operator using the simplified process.
The framework allows storage systems to draw electricity from both the co-located PV system and the grid, but requires compliance with safety provisions, including overload protection and real-time monitoring of household electrical limits.
Industry representatives said technologies enabling dynamic load management and thermal protection could allow higher effective system utilization within the 800 VA constraint, particularly when paired with battery storage.
The changes follow growing deployment of plug-in solar devices in Germany, where installation rates have accelerated in recent years. According to figures cited in the interview, uptake of plug-in systems is expanding significantly faster than conventional residential rooftop PV.
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India’s solar additions surged 70% year on year to 29.5 GW in the first three quarters of 2025, driven by rapid utility-scale and rooftop deployment, according to JMK Research.
Image: dheeraj sharma, Unsplash
From pv magazine India
India installed 29.5 GW of solar and 4.96 GW of wind capacity in the first nine months of 2025, according to JMK Research.
Utility-scale solar accounted for about 22.5 GW of the total, marking a 70.3% increase from the same period in 2024. Roughly half of that capacity, 11.1 GW, was commissioned in the third quarter alone.
Rooftop solar installations reached 5.8 GW during the period, up 81.6% year on year, with 46% completed in the third quarter. The off-grid and distributed solar segment added 1.17 GW, representing a 12.7% annual increase.
Data from the Ministry of New and Renewable Energy show India’s total renewable capacity stood at around 247.3 GW as of September 2025. Solar accounts for about 52% of that total, followed by wind at 21%, large hydro at 20%, bioenergy at 5%, and small hydro at 2%.
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800MW Springwell Solar Farm by EDF Power Receives Greenlight, Largest of its Kind in the UK  Construction Review
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Scientists in Australia claim that TOPCon cells are rapidly closing the open-circuit voltage gap with heterojunction counterparts, now under 10 mV, while offering greater wafer tolerance and high industrial scalability. Despite slightly lower efficiency, TOPCon-based perovskite/silicon tandems can achieve a levelized cost of energy comparable to heterojunction-based tandems due to reduced fabrication costs, according to the researchers.
Figure 3(1)
Image: Australian National University
From pv magazine Global
Heterojunction (HJT) solar cells generally achieve slightly higher open-circuit voltage than TOPCon devices, reflecting differences in surface passivation and recombination losses.
The advantage of HJT stems from its use of intrinsic amorphous silicon layers, which provide excellent surface passivation and reduce carrier recombination. Although TOPCon technology has significantly narrowed the gap through advanced tunnel oxide passivated contacts, a slight difference in performance remains, contributing to HJT’s marginally higher efficiency potential.
With this in mind, researchers at the Australian National University (ANU) have sought to quantify this distance and provide a realistic roadmap for TOPCon to remain competitive as a bottom cell technology in the emerging perovskite-silicon tandem segment.
Open-circuit voltage gap
“We analyzed recent incremental innovations in TOPCon technology and show that the traditional open-circuit voltage advantage of HJT cells is rapidly diminishing, now approaching a gap of less than 10 mV,” the research’s corresponding author, Rabin Basnet, told pv magazine. “Building on this, we presented quantitative modelling of tandem efficiency potential, benchmarking TOPCon and HJT bottom cells under realistic assumptions. This enabled us to identify the origins of the current performance gap and the conditions under which TOPCon-based tandems can become competitive.”
In the paper “TOPCon-based bottom cells for perovskite/silicon tandem solar cells,” published in Joule, Basnet and his colleagues explained that, in the last two years, TOPCon cells were able to narrow the open-circuit voltage gap with HJT counterparts to under 10 mV, with the laser-assisted firing (LECO) process enhancing front-side contact passivation and enabling a 740 mV open-circuit voltage in recent mass-produced TOPCon cells.
Furthermore, they noted that innovations in contact optimization and metallization have increased TOPCon fill factors above 84%, approaching HJT performance. However, simulations of two-terminal (2T) perovskite/silicon tandems still indicate that HJT-based tandems achieve higher power conversion efficiencies due to superior fill factor and short-circuit current.
Mass production
The research team stressed that TOPCon cell mass production is less demanding in wafer quality due to poly-Si gettering, whereas HJT requires high-purity wafers and pre-gettering steps to mitigate defects, increasing cost and complexity. It also highlighted that TOPCon fabrication involves 8–10 steps, including boron-diffused front emitters and n⁺ poly-Si rear contacts with silicon oxide (SiOx) interlayers, while HJT involves only 4–6 low-temperature steps, although it also requires amorphous and doped silicon layers, TCO deposition, and low-temperature metallization.
“Despite involving fewer process steps, HJT cell fabrication remains more costly than TOPCon,” the academics said. “The Capex per GW for TOPCon manufacturing lines is approximately two to three times lower than that of HJT lines and remains competitive with that of previous mature PERC technology based on p-type wafers. This cost advantage stems primarily from equipment differences: TOPCon relies on low-cost low-pressure chemical vapor deposition (LPCVD) tools, whereas HJT requires relatively expensive plasma-enhanced chemical vapor deposition (PECVD) tools, which account for the majority of HJT line Capex.”
LCOE
Sustainability and scalability are also presented as additional constraints for HJT, especially due to indium-based transparent conductive oxidse (TCOs), which may limit production beyond 40 GW. TOPCon’s combination of lower cost, industrial compatibility, and high efficiency makes it more suitable for large-scale perovskite/Si tandem manufacturing, according to the researchers.
Moreover, levelized cost of energy (LCOE) modeling showed that, despite slightly lower efficiency, TOPCon-based tandems can achieve comparable or lower LCOE than HJT-based tandems due to reduced fabrication costs. “These findings are reflected in the strategic focus of some of the leading PV manufacturers, such as JinkoSolar, Trinasolar, and Hanwha Qcells, on the development of tandem solar cells utilizing TOPCon as the bottom cell,” the academics emphasized.
Despite these promising developments, some challenges remain for TOPCon as the silicon bottom cell in tandem architectures. These include maintaining effective passivation on textured surfaces, mitigating parasitic absorption in poly-Si contacts, and ensuring stability during high-temperature integration of the top cell. Overcoming these challenges is critical to fully realize the optical and electrical gains needed to boost the efficiency of 2T tandems and will require innovative approaches in material engineering, such as sub-micron texturing, optimization of thinner doped poly-Si layers, and incorporation of hydrogen-rich capping layers.
“Overall, our work reframes TOPCon as a realistic, industry-compatible pathway for the scalable manufacturing of perovskite/silicon tandem solar cells,” Basnet concluded. 

GB NEWS
By Matt Gibson, 
Published: 08/04/2026
Updated: 08/04/2026
It could power more than 180,000 homes a year, the equivalent of half the homes in Lincolnshire
A solar farm the size of 1,800 football pitches has been given the go-ahead, despite locals claiming it will “industrialise a vast rural landscape”.
Springwell Solar Farm is a proposed 800-megawatt project with battery storage and supporting grid connection infrastructure in North Kesteven, Lincolnshire.

Springwell Solar Farm is a proposed 800-megawatt project with battery storage and supporting grid connection infrastructure in North Kesteven, Lincolnshire

|

PA

The topic of solar farms has split opinion | PA

According to the developer, it could power more than 180,000 homes a year, the equivalent of half the homes in Lincolnshire.
However, critics have labelled the decision to approve the huge scheme as a “crystal-clear example of Net Zero zealotry”.
The site is 1,280 hectares, equivalent to nearly 2,000 football pitches. The plans faced stiff opposition from locals and the County Council also sent a letter of objection.
But because the development has such a vast generating output, it was classed as a Nationally Significant Infrastructure Project.
This meant the final decision fell to central Government. It was given the green light by Energy Secretary Ed Miliband, making it the 25th nationally significant clean energy project approved by Labour since the 2024 General Election.
Energy Minister Michael Shanks said the scheme would help UK energy security and bring down costs.
Springwell Solar Farm is a proposed 800-megawatt project with battery storage and supporting grid connection infrastructure in North Kesteven, Lincolnshire
PA
He said: “We are driving further and faster for clean homegrown power that we control to protect the British people and bring down bills for good.
“It is crucial we learn the lessons of the conflict in the Middle East – solar is one of the cheapest forms of power available and is how we get off the rollercoaster of international fossil fuel markets and secure our own energy independence.”
Ahead of the decision, a meeting of Lincolnshire County Council heard that 42 per cent of the site was classed as “best and most versatile” (BMV) agricultural land.
Of the 591 hectares set to be covered by solar panels, 35 per cent was classed BMV. The meeting heard claims that the development would negatively impact food production.
The council committee voted to send a written objection to the application. It acknowledged that the project would produce clean, renewable energy but concluded that the positive impacts were outweighed by negatives.
Caroline Johnson, MP for Sleaford and North Hykeham, told Lincolnshire World that the decision showed “utter contempt for our local communities, our local landscape and Lincolnshire’s national role in food production”.
She said: “This crystal-clear example of Net Zero zealotry from this government highlights their complete disregard for rural communities and my affected constituents.
“The decision to allow thousands of acres of agricultural land to be turned over to solar installations and cause huge impacts on local residents while doing so is completely irrational.
“I am so sorry to all who have fought so diligently against the Springwell application. I will not be giving up my fight against all mega solar farms.”
Local residents had previously objected to the project, branding it “monstrous”.
One wrote to planners: “From the outset, it has felt like local voices have been ignored and this entire process treated as a formality rather than a fair consultation.
“I urge the Planning Inspectorate to reject this proposal and protect Lincolnshire’s countryside and people.”
Another claimed: “This application will industrialise a vast rural landscape popular as a walking spot.”
Campaigners from the Springwell Solar Action Group said ahead of the decision: “We have tried throughout this process to provide the detail from local knowledge on how the monstrous Springwell development and subsequent developments will destroy this beautiful part of Lincolnshire.
“From the very start of this process, it has been abundantly clear to our communities that the applicant and its representatives felt that this was simply a rubberstamping exercise.
“Throughout the process, local concerns have been ignored.” A letter written on behalf of Mr Miliband said he agreed with the recommendations from planners that the scheme should go ahead.
It read: “The examining authority concluded that the proposed development satisfies the definition of low carbon infrastructure and maintained that there is an urgent need for the proposed development in order for the Government to meet its energy security and net zero targets.”
It added: “The examining authority was satisfied that there would also be clear benefits in relation to climate change as a result of the proposed development.”

Our Standards: The GB News Editorial Charter

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The 185 MW wind-solar hybrid project commissioned at Kalavad serves 17 corporate customers under group captive model to support demand of energy-intensive manufacturing.
Image: CleanMax
Clean Max Enviro Energy Solutions, a renewable energy solutions provider for the commercial and industrial sector, has commissioned a 185 MW hybrid wind-solar power project at Kalavad, Gujarat.
The project, developed over 12 months, supplies renewable power to 17 corporate customers under the group captive model. In this model, customers invest equity in the project complying with captive rules under the Electricity act, while securing long-term access to clean energy. Offtakers include Apar Industries Ltd and Borosil Renewables Ltd among others.
The Kalavad project strengthens CleanMax’s hybrid portfolio in Gujarat, supporting more consistent renewable energy supply aligned with round-the-clock industrial demand. With this addition, the company’s total operational capacity in Gujarat has reached 844 MW as of March 31, 2026.
Once stabilised, the project is expected to add annual revenues exceeding INR 165 crore from FY2027 onwards. Backed by 25-year fixed-tariff power purchase agreements (PPAs) with customers, it provides clear visibility and stability of cash flows over its lifecycle.
Once fully operational, the Kalavad project is expected to offset 3.61 lakh tonnes of CO₂ emissions annually, equivalent to the environmental benefit of planting nearly 20.9 million trees annually.
CleanMax’s cumulative operational energy sale capacity stands at 3.1 GW as of March 31, 2026, spanning multiple states and supporting a diverse customer base.
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Sunsure Energy, a provider of round-the-clock renewable energy solutions for businesses and utilities, has signed three long-term solar open-access power purchase agreements (PPAs) with Wonder Cement.
Sunsure
Sunsure Energy, a provider of round-the-clock renewable energy solutions for businesses and utilities, has signed three long-term solar open-access power purchase agreements (PPAs) with Wonder Cement for a cumulative capacity of 30 MWp. Under the continued partnership, Sunsure has begun supplying power to Wonder Cement’s facilities in Dhule, Maharashtra and Aligarh, Uttar Pradesh, from its 150 MWp plant in Solapur and 49 MWp plant in Augasi, respectively.
The agreements will help Wonder Cement offset a total of 33,000 metric tonnes of CO2 emissions annually, equivalent to planting 1.5 million trees, supporting their commitment to integrate renewable energy into their operations.
By partnering with Sunsure, Wonder Cement will be able to displace 67% of their electricity consumption in Dhule facility and 52% of their electricity consumption in Aligarh facility with clean power, significantly reducing its reliance on grid power.
Sunsure is backed by Partners Group AG with an equity commitment of $400 million towards its vision of building the largest industrial decarbonisation company in India and Southeast Asia. The company currently has 700 MW of operational assets and 7.1 GW under various stages of development across Maharashtra, Tamil Nadu, Uttar Pradesh, Rajasthan, and Karnataka, with a target of reaching 10 GW by 2030.
 
 
 
 
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