Solar Now

J&V Energy, a Taiwan-headquartered developer, has acquired a 187MW portfolio of operational solar assets in Taiwan from a fund managed by Global Infrastructure Partners, a subsidiary of global asset owning giant BlackRock. 
The portfolio includes 42 operational solar projects across central and southern Taiwan, with a combined installed capacity of 187MW. The assets are projected to generate around 270 million kWh of renewable electricity annually and have a remaining operational lifespan of more than 15 years. 
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The transaction is expected to close in Q3 2026.s. Financial terms of the acquisition were not disclosed. Once completed, the portfolio will be integrated into J&V Energy’s operating, asset management and electricity retail platforms in Taiwan. 
“This acquisition fits well with our strategy of building a high-quality, income-producing renewables portfolio anchored by long-dated, fully contracted cashflows. The 187MW portfolio provides stable, predictable revenue at scale, and we see clear opportunities to add further value through J&V Energy’s integrated operating, asset management and offtake capabilities,” said group chief investment officer of J&V Energy, Jerome Tan. 
According to the company, the acquisition strengthens its integrated renewables platform in Taiwan and is significant in expanding its position as an independent power producer (IPP). The additional capacity will also bolster the supply pipeline of GREENET, J&V Energy’s green power retail subsidiary. 
Earlier this year, a consortium led by GIP agreed to acquire AES Corporation in a US$10.7 billion transaction. The consortium also includes EQT Infrastructure VI, the California Public Employees’ Retirement System (CalPERS) and the Qatar Investment Authority. Under the terms of the agreement, AES shareholders will receive US$15.00 per share in cash. The transaction is expected to close in late 2026 or early 2027. 

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Solar PV and wind are now the cheapest sources of power globally, with co-located hybrid systems increasingly delivering round-the-clock electricity at fossil fuel-competitive costs in high-resource regions, according to a new report by the International Renewable Energy Agency (IRENA).  
In its report titled ‘24/7 renewables: The economics of firm solar and wind’, IRENA highlighted that while renewable energy deployment has scaled rapidly on the back of falling costs, the next phase of the energy transition will be defined by system adequacy and flexibility – ensuring clean electricity is available whenever and wherever it is needed. 
The report introduced a new project-level metric, “firm levelised cost of electricity (LCOE)”, to assess the cost of delivering continuous electricity from hybrid systems combining solar PV, onshore wind and battery energy storage systems (BESS).  
According to IRENA’s analysis, firm renewable electricity costs have declined rapidly across all major technologies and markets, driven primarily by sharp reductions in solar PV and battery storage costs. 
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In high-quality solar resource regions, co-located solar PV and storage systems are already capable of delivering firm electricity at costs below fossil fuel benchmarks. The report said that in 2025, firm LCOE for solar-plus-storage systems in strong solar and wind regions ranged from around US$54-82/MWh, down from more than US$100/MWh in 2020. 
Further cost reductions are expected, with IRENA projecting firm LCOE could fall by around 30% by 2030 and approximately 40% by 2035, bringing costs below US$50/MWh at the best-performing sites. 
The agency’s analysis of 252 utility-scale solar PV projects commissioned in 2024 in China shows that a significant majority can deliver firm electricity below US$100/MWh, with minimum firm costs as low as US$30/MWh at a 90% reliability level. Even at 99% reliability, costs rise only modestly to around US$46/MWh. 
Between 2010 and 2024, global weighted average total installed costs for solar PV fell by 87% to US$708/kW, while levelised costs of electricity declined by 90% to US$44/MWh. 
Battery energy storage systems experienced even steeper declines, with costs falling by 93% over the same period from US$2,634/kWh in 2010 to US$197/kWh in 2024. Industry data cited in the report suggests that battery system prices fell by around 30% in 2025 alone, reaching their lowest recorded levels. 
The report stated that in 2025, utility-scale solar PV and onshore wind both cost around US$40/MWh globally, less than half the cost of new combined-cycle gas turbines, which exceeded US$100/MWh. 
In China, firm solar-plus-storage already undercuts both new coal and gas generation, while in markets such as Saudi Arabia, firm solar electricity is approaching parity with gas-fired generation even where fuel costs are relatively low. 
IRENA also noted that in several economies, co-located wind and solar systems with storage are now competitive with the operating costs of existing fossil fuel plants, challenging not only new build economics but also the viability of continued operation of legacy assets. 
The report concluded that the pace of deployment of firm renewable electricity systems will be one of the most consequential factors shaping the global energy transition in the coming decade. 
To read the full version of this story, visit PV Tech, where it was originally published.

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Today, as more countries commit to long-term net-zero goals, green and low-carbon development has become a shared global priority. With the accelerated adoption of renewable energy worldwide, scenario-based applications are becoming an important growth point for the photovoltaic market in the next stage.
Driven by cost advantages and clean power output, renewable energy is accelerating the start of a new cycle of scenario-based applications, photovoltaics increasingly deployed in high-consumption, high-cost, and electricity-constrained environments. The need is especially strong in off-grid operations—such as oil and gas extraction and mining – where diesel generation remains costly and inefficient.
According to relevant data, electricity generated from traditional fossil-fuel-based sources—such as coal, natural gas, and diesel—remains significantly more expensive and less flexible than renewable alternatives, while also facing growing environmental constraints.
In particular, the cost of diesel-based power generation is approximately 275% higher than that of photovoltaic power generation. In addition to high fuel costs, diesel generator systems are challenged by limited flexibility, high maintenance requirements, and increasing environmental pressure.
Against this backdrop, there is a clear and growing demand for standardized, mobile solar solutions that can significantly reduce operating costs while improving efficiency and sustainability.

Based on market demand, GCL launched the EcoPower Mate series in November 2025 – a mobile photovoltaic system designed for operations facing constrained or complex energy conditions worldwide. Built for extreme environments, rapid deployment, and high energy efficiency, EcoPower Mate offers a new approach to zero-carbon transformation in traditional high-energy-consuming scenarios.
Tackling Industry Pain Points: Dual Product Configurations Optimized for Diverse Scenarios
Traditional diesel generators have long dominated outdoor operations, yet they come with significant drawbacks – severe carbon emissions and noise pollution, high power generation costs, insufficient deployment flexibility, and difficulty in coping with extreme weather and complex terrain.
To address the aforementioned issues, EcoPower Mate offers two product configurations: wheeled and rail-mounted, covering the needs of different application scenarios.
The wheeled PV container features an integrated design with container doors, built-in inverters, DC junction boxes, power distribution modules, and drive systems. Measuring 12.16m × 2.53m × 2.89m, it is lightweight and highly portable. This product requires no prefabricated tracks and can be deployed on flat surfaces such as concrete or gravel, with local compaction and leveling or driving in short steel stakes, making it ideal for flat terrain and reducing on-site construction work.
The rail-mounted PV system is designed for complex and varied road conditions. It uses a rail foundation equipped with mechanical support arms and secure module-fastening systems. A single rail can be up to 100m long, and the body size is 6.058m × 6.058m × 2.438m. This configuration ensures stable operation in rugged environments typical of oil and gas exploration and mining sites.
Both products are equipped with GCL’s SiRo T series high-efficiency photovoltaic modules, delivering a maximum power output of up to 520 W and a module efficiency of up to 23.37%. The modules are compatible with mainstream inverters on the market and have extremely strong adaptability.
Three Core Values Redefining the Benchmark for Mobile Solar Power
Beyond scenario-specific configurations, EcoPower Mate delivers three key advantages—flexibility, cost efficiency, and environmental performance—setting a new standard for mobile outdoor energy solutions.
EcoPower Mate offers rapid plug-and-play deployment, enabling installation and power generation within minutes—reducing setup time by up to 90% compared with traditional PV installations. In extreme weather conditions, the user can relocate all modules into the container within 30 minutes of receiving the weather alert to provide effective protection against sandstorms, heavy rainfall, and other severe environmental impacts. A smart power management system adjusts output in real time based on load requirements, while the reusable design allows the entire system to be moved easily between sites.

EcoPower Mate helps reduce operational costs through automated installation, cutting labor requirements by more than half. Its reusable design reduces equipment wear by more than 30%, and the self-cleaning function improves the power generation efficiency of the modules by more than 40%. Compared to diesel power generation, solar power can cost as low as USD 0.10–0.12 per kWh—up to 60% lower than diesel generation—offering substantial long-term savings and improved return on investment.
EcoPower Mate also delivers strong environmental benefits. The product operates with low operating noise and no greenhouse gas or air pollutant emissions, supporting operators’ sustainability targets. For industries such as oil and gas, where environmental regulations are tightening, this solution helps reduce carbon footprints and supports broader corporate ESG goals. 
Multi-Scenario Adaptation: Building a Zero-Carbon Energy Ecosystem
With its strong environmental adaptability and system compatibility, supports a wide range of applications, including off-grid, hybrid, and grid-connected systems. It is also compatible with multiple energy storage configurations, enabling flexible deployment across industries seeking to reduce emissions.
In off-grid system scenarios – including, but not limited to, remote islands, mining operations, agricultural and food production sites, outdoor events, and oil and gas facilities—the EcoPower Mate provides a stable and clean alternative to traditional fossil-fuel-based power solutions. In hybrid or grid-connected systems, it can integrate with existing power infrastructure, enhancing energy self-sufficiency and supporting low-carbon industrial operations.
The solution can also support grid-connected applications such as data centers, supplying renewable energy to power high-demand computing operations and contributing to more sustainable digital infrastructure.
EcoPower Mate offers 50 kW and 125 kW energy storage options, both of which can be expanded through parallel configuration. A single system support up to 1 MWp of solar capacity and 1 MWh of storage. When combined in parallel, deployments can scale to 2 MWp of PV, 2.6 MWh of storage, and 1.25 MW of AC output, meeting the needs of larger operations.

The first batch of EcoPower Mate units has completed installation, commissioning, and system testing at GCL’s Hefei factory, with all performance metrics meeting design specifications. The product has officially entered the market application stage.
Looking ahead, the EcoPower Mate will expand internationally, with installations planned in Saudi Arabia in Q1 2026, marking the start of its overseas deployment.
With more than 350 global companies committed to RE100 targets and industries advancing their decarbonisation strategies, EcoPower Mate is positioned to become an essential solution for reducing emissions in energy-intensive operations worldwide.
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Photo: EVN Macedonia
Published
May 13, 2026
Country
North Macedonia
Author
Igor Todorović
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Published:
May 13, 2026
Country:
North Macedonia
Author
Igor Todorović
Comments:
0
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North Macedonia’s power distribution system operator (DSO) EVN Macedonia, which also generates electricity, inaugurated a battery energy storage system co-located with a PV plant in the country’s northeast. It will enable storing the energy produced during the day, to be used at the most favorable time, contributing to stability, flexibility and efficiency of the energy system, the company said.
The BESS in Probištip has a 10 MW capability and a duration of two hours, translating to 20 MWh. It is the largest within the Austria-based EVN Group as well as the largest licensed battery facility in North Macedonia, the announcement reads.
Earlier, Turkish contractor YESS Power completed a BESS of 30 MW and 60 MWh at its client Mey Energy’s solar power plant in Novaci. It is set to enter commercial operation in the third quarter, according to the latest update.
Fortis Energy has a similar project in the same country. It is planning a large photovoltaic system with BESS in Serbia, too, while already building one in neighboring Albania. Another hybrid facility is under construction in North Macedonia. The first grid-scale battery system in Albania recently came online. The other projects in the Western Balkans are still in earlier stages.
CATL and K Star supplied the equipment
EVN Macedonia started production at the solar park, of 10.9 MW in peak capacity, more than two years ago.
Board members, managers of subsidiaries, officials from the Municipality of Probištip, university professors and representatives of Intebako, the contractor, attended the launch ceremony.
“Soon, the system’s capacity will be doubled to 40 MWh. The equipment for it has already been delivered and is currently in the installation phase,” Chairman of the Management Board Wolfgang Maier stated.
The BESS consists of CATL’s lithium-iron-phosphate (LiFePO4 or LFP) units. It is envisaged to last ten years or 10,000 cycles. The containers with batteries and K Star power conversion systems (PCS) span 580 square meters. The facility received a license on April 9.
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North Macedonia
13 May 2026 – EVN Macedonia commissioned a battery energy storage system within its Probištip photovoltaic plant in North Macedonia
Region/EU, Serbia
13 May 2026 – Companies in the region have challenges in energy security, decarbonization and digitalization, and the key is investing in production, the grid and batteries, according to the panel on power system transition at Belgrade Energy Forum 2026
Region/EU, Serbia
12 May 2026 – Ivan Asanović, CEO of Montenegro’s transmission system operator, participated in the panel on transmission grid development at BEF 2026
Region/EU, Serbia
12 May 2026 – Jelena Matejić, General Manager of Elektromreža Srbije, took part in a panel on transmission grids at Belgrade Energy Forum 2026
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Published on May 13, 2026
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Abu Dhabi Solar project advances as JinkoSolar signs a 2GW photovoltaic module supply agreement with Masdar. The deal supports the UAE’s $6 billion round-the-clock renewable energy scheme in Abu Dhabi. The project combines a 5.2GW solar PV plant with a 19GWh battery energy storage system. Furthermore, Abu Dhabi Future Energy Company (Masdar) leads development in collaboration with Emirates Water and Electricity Company (EWEC). Construction began in October 2025 with Larsen & Toubro and PowerChina serving as contractors. Consequently, the scheme targets continuous baseload renewable generation. It is widely recognised as the world’s first gigascale RTC renewable energy project.
JinkoSolar will supply its Tiger Neo series modules for the Abu Dhabi Solar project. The company will deploy N-type TOPCon technology tailored for desert performance conditions. Moreover, Masdar selected JinkoSolar earlier alongside JA Solar as preferred PV suppliers. In addition, Contemporary Amperex Technology (CATL) provides battery energy storage systems for the RTC project. The agreement strengthens integration across solar and storage technologies. However, execution demands tight coordination across global supply chains.
Masdar leads development with EWEC to ensure long-term power stability. Furthermore, the project directly addresses intermittency challenges in solar generation. It delivers dispatchable renewable baseload power using integrated storage systems. Consequently, the design sets a benchmark for hybrid energy infrastructure globally.
The Abu Dhabi Solar project builds on Abu Dhabi’s earlier utility-scale solar pipeline, including the planned Al Ajban Solar PV Project contract award process, which signaled continued expansion of independent power projects under EWEC’s procurement framework. While Al Ajban focused on a conventional 1.5GW photovoltaic IPP model, the Abu Dhabi Solar project advances this trajectory by integrating 5.2GW of solar capacity with a 19GWh battery energy storage system to enable round-the-clock renewable generation.
Consequently, both developments demonstrate a structured evolution in Abu Dhabi’s solar strategy, moving from standalone PV projects toward hybrid baseload renewable systems designed to stabilise grid supply and reduce intermittency.
Construction of the Abu Dhabi Solar project began in October 2025. Larsen & Toubro and PowerChina lead major EPC works across the site. Moreover, contractors focus on large-scale PV installation and high-voltage grid integration. The project requires complex sequencing due to its hybrid solar and storage structure. In addition, engineering teams prioritize efficiency under extreme desert climate conditions.
Grid integration remains critical to operational success. Furthermore, phased commissioning ensures stable and reliable energy delivery. However, the project scale introduces significant logistical and technical challenges. Consequently, developers apply advanced project management and digital monitoring systems. This ensures alignment between construction milestones and energy output targets.
The RTC renewable energy scheme aims to serve as a global benchmark. Furthermore, developers expect replication in other high solar irradiance regions. It demonstrates the viability of combining utility-scale solar with long-duration storage. In addition, it supports global decarbonisation and energy transition objectives.
JinkoSolar continues expanding its global utility-scale portfolio. It recently secured multi-gigawatt supply contracts across Saudi Arabia. Moreover, this strengthens its position in high-capacity PV module markets. Consequently, the company remains a key supplier in large-scale renewable infrastructure development.

Project Name: Abu Dhabi Round-the-Clock (RTC) Solar & Storage Project
Location: Abu Dhabi, United Arab Emirates
Total Value: $6 billion
Solar Capacity: 5.2GW photovoltaic plant
Battery Storage: 19GWh BESS
Technology: N-type TOPCon Tiger Neo PV modules
Developer: Masdar in partnership with EWEC
Contractors (EPC): Larsen & Toubro, PowerChina
Preferred PV Suppliers: JinkoSolar, JA Solar
BESS Supplier: CATL
Construction Start: October 2025
Project Type: Utility-scale solar + battery hybrid (RTC baseload renewable system)
Key Objective: Provide continuous renewable baseload power and reduce intermittency
Developer: Masdar
Power Offtaker / Utility Partner: Emirates Water and Electricity Company (EWEC)
PV Module Supplier: JinkoSolar
Additional PV Supplier: JA Solar
Battery Storage Supplier: Contemporary Amperex Technology (CATL)
EPC Contractors: Larsen & Toubro; PowerChina
Technology Scope: N-type TOPCon PV systems, grid-scale BESS integration
Project Category: Gigascale renewable energy infrastructure (solar + storage hybrid)
Strategic Role: Baseline renewable power generation and grid stability enhancement
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Solar PV project performance in the US can be significantly impacted by hailstorms and stowing methods, and projects face new challenges in the form of fire safety.
This is according to the latest report from US-based climate insurance provider kWh Analytics, which published the 2026 edition of its annual Solar Risk Assessment (SRA) report this week. The previous year’s report highlighted the impacts of hail on US solar projects—noting that hail accounted for 73% of financial losses for US solar, despite accounting for just 6% of all loss incidents—and the impacts of hail feature prominently in this year’s report.
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Specifically, a piece authored by kWh Analytics’s Nicole Thompson and GroundWork Renewables’ Colin Sillerud argues that better hail projections are required for projects in the US states. For 52% of the contiguous US, “some mitigation beyond standard 2mm/2mm glass modules is needed to keep risk below the threshold,” which is defined as hail damage driving losses of 10% of the asset’s overall value. The piece also argues that “robust stow”—the practice of stowing modules at an angle of at least 70 degrees—is a more effective tool in minimising the impacts of hailstorms than building more resilient modules by itself.
The report also notes that fire losses are a significant challenge for project operation, with a piece from kWh Analytics’ Charity Sotero describing it as “the second-largest loss driver,” based on analysis of over US$150 billion of renewable energy loss data. This is particularly significant because just 4% of PV fire loss incidents occur in “high-wildfire risk” areas, suggesting that it is not environmental conditions, but mechanical failures that drive these losses.
Indeed, the report notes that inverters are responsible for 44% of all PV fires and 80% of all equipment-driven brush fires. The significance of these losses can also vary considerably, with damage ranging “widely” from “zero loss” to as much as 80% of the total asset value.
The report also notes that long-term tracker operation can have an impact on a project’s operational effectiveness. A piece from Frank Oudheusden and Chrisopher Needham of Azimuth Advisory Services describes the impacts of the “propeller effect”, where a row of modules on a tracker gradually rotates from the actuator towards the row end; this shift in actual module angle can lead to “localised shading losses” of over 30%.
The same piece notes that individual modules on an array can display a “twist” of one degree; this is not a significant angle, but the report notes that “this motion repeats with each tilt adjustment, resulting in hundreds of thousands of stress cycles over a project lifetime,” which is worth noting when considering a project’s long-term efficacy.
“Delivering durable, reliable, affordable renewable energy infrastructure requires the honest, data-driven exchange this report is built on,” said kWh Analytics CEO Jason Kaminsky. “The valuable research from this year’s SRA contributors reflects the rigorous thinking our industry needs to build robust infrastructure in a heightened risk environment. We are grateful for their meaningful collaboration.”

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India’s power grid struggles to handle excess solar energy. ReNew Energy Global Plc faces power curtailment, affecting earnings. The company is investing in battery storage to balance supply and demand. Rising costs from global events add to challenges. Future projects will focus more on solar power.
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The Trump Administration’s decision to repeal of the 30% home solar tax credit in 2025 looked like the end of the road for subsidized residential rooftop solar projects, but homeowners can still get it under certain circumstances – until America’s 250th birthday, that is.
SKIP THE STORY: I’m ready to panic now!
The 30% federal tax credit (Section 25D) for residential solar is, of course, still dead. The credit was very publicly expired on December 31st, 2025 — but that just meant you couldn’t get that 30% back for systems you bought. See, Section 25D (the one that the Trump Administration killed) only applied to taxpayers with an ownership interest in their PV systems, but leases?
Leases are still on the table, though. And – just as we’ve seen with electric vehicle tax credits over the years, the rules for leases are a little bit different than those for purchases.
What that means for home solar is that, under Section 48E of the Federal tax code, qualified solar companies that own a PV system can continue to claim a credit of up to 30% on those through the end of 2027, and if you’re leasing your system or entering into a power-purchase agreement (PPA) with a solar installer, the company can pass some or all of that incentive on to you. The “catch” is that they can only pass along tax credits they actually recieve, and while while Section 48E technically survives through the end of 2027, many solar companies are racing to “safe harbor” projects before July 4, 2026 – the date many in the industry see as the last meaningful chance to lock in the full 30% credit.
The new federal bill sets strict deadlines for commercial solar projects to receive the full 30% tax credit. Projects that begin construction by July 4, 2026 must be placed in service within four calendar years. For projects that begin construction after July 4, 2026, the credit is only available if the project is placed in service by December 31, 2027.
STRAIGHT UP SOLAR
That July-December window is pretty tight, and is likely to seem even tighter if a prolonged conflict in Iran creates a larger impact on global shipping and supply chains. That said, for solar projects initiated before the big 250th party, the 30% solar tax credit could mean a lower monthly payment on a lease or PPA, or even totally eliminated up-front costs.
Those details are ultimately between you and the company you decide to move forward with. The key takeaway, however, is that the 30% solar incentive isn’t dead dead. It’s just mostly dead – and if you’re shopping for solar, sooner is going to be a lot better for you than later.
At the center of the post-2025 solar tax credit is US Code § 48E, often called the Clean Electricity Investment Credit. Unlike the now-expired residential credit (the previously-mentioned Section 25D), which was claimed directly by homeowners, Section 48E is a commercial investment tax credit designed to incentivize businesses that own “clean energy equipment,” which currently includes both solar panels and battery energy storage systems (along with natural gas fuel cells, among other things).
Under this provision, a company that owns a solar installation can claim a tax credit worth up to 30% of its qualified investment in the project then enter into a third-party ownership model (lease or PPA) with the homeowner.
As the July 4th safe haven cutoff date indicates above, however, there are some caveats here that could complicate your particular installation – which allows me to segue nicely into the following disclaimer …
Tax law is a messy, complicated, and high-stakes field. Federal tax credits, state laws, utility programs, and the fine print in the contracts from company to company can overlap or even contradict each other, and navigating any part of it isn’t especially intuitive. That complexity is exactly why the smart people you know hire accountants and tax professionals to make incentives work for them, and you should do the same.
If you’re considering a lease or PPA, a conversation with a qualified professional installer can help you understand what’s being offered and how a given deal is being structured. Take that information to your accountant to understand what’s real, what’s marketing, and what actually saves you money.
Finally, if there’s money on the table, make sure you don’t leave it there! Remember: US tax law could be a single line codified into law. Instead, it’s 4,000+ pages of densely worded legalese. Get you an expert, and get what your democratically elected leaders decided you have coming to you.
Unless, you know, you actually don’t care about money!
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If you’re considering going solar, it’s always a good idea to get quotes from a few installers. To make sure you find a trusted, reliable solar installer near you that offers competitive pricing, check out EnergySage, a free service that makes it easy for you to go solar. It has hundreds of pre-vetted solar installers competing for your business, ensuring you get high-quality solutions and save 20-30% compared to going it alone. Plus, it’s free to use, and you won’t get sales calls until you select an installer and share your phone number with them. 
Your personalized solar quotes are easy to compare online and you’ll get access to unbiased Energy Advisors to help you every step of the way. Get started here.
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A coalition of US solar manufacturers has filed a new formal request with the US Department of Commerce to initiate an anti-circumvention inquiry into crystalline silicon (c-Si) PV cells and modules assembled in Ethiopia using Chinese-origin components.
The Alliance for American Solar Manufacturing and Trade (AASMT) filing alleges that two solar manufacturers – Toyo Solar and Origin Solar Manufacturing – are using Chinese-origin wafers in solar cells made in Ethiopia, which are then assembled into modules either in Ethiopia or Vietnam for export in the US.
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The coalition – which includes First Solar, Hanwha QCells, DYCM Power, Great Lakes Solex PR, Silfab Solar, Suniva, Swift Solar (as Solx) and Talon PV – alleges that manufacturers are “exploiting Ethiopia as the latest export platform to circumvent existing antidumping and countervailing duty (AD/CVD) orders on solar products by routing Chinese wafers and components through minimal Ethiopian solar manufacturing operations before shipping finished cells and modules to the United States”.
Both Toyo Solar and Origin Solar have been producing solar cells in Ethiopia. In the case of Toyo, the company began operations at its facility last year with an annual nameplate capacity of 2GW and has already planned to double that capacity with a second manufacturing cell processing plant in Hawassa.
Rhone Resch, chief strategy officer at Toyo Solar, rebutted the coalition’s claims in a statement to PV Tech.
“Toyo Solar is the largest Japan-owned solar manufacturer of n-type solar cells and modules and is building a substantial domestic manufacturing footprint for both solar cells and modules in the United States in support of our utility-scale customers,” Resch said. “Currently, all solar cells manufactured in Ethiopia use exclusively polysilicon supplied from the US and Malaysia, and our wafers are processed in Southeast Asia. We plan to vigorously clarify these facts through the appropriate official channels.”
Resch recently spoke with PV Tech Premium about the company’s US efforts to build domestic manufacturing capacity (subscription required) with a facility in Texas, aiming to reach 2GW of annual module nameplate capacity this year, along with plans for a domestic cell processing plant.
Meanwhile, Origin Solar began exporting its first batch of solar cells to the US earlier this year, according to public owned company Industrial Parks Development Corporation (IPDC). The manufacturer has a solar processing facility with a 4.2GW annual nameplate capacity of solar cells in Ethiopia.
According to the AASMT, US imports of Ethiopian solar products went from nothing in June 2025 to US$300 million by December 2025.
“What we’re seeing in Ethiopia follows a familiar playbook,” said Tim Brightbill, Partner and Co-Chair of the Trade Practice at Wiley Rein LLP. “For over a decade, state-subsidised manufacturers have responded to U.S. trade enforcement by relocating minimal finishing operations to the next available country, while continuing to source nearly all their inputs from the same foreign suppliers. American solar manufacturing is at an inflection point: with billions invested, thousands of jobs created, and real capacity coming online, we are not going to stand by and allow serial tariff evasion to undercut that progress.”
This new request from the coalition comes as an AD/CVD case against three Asian countries – India, Indonesia and Laos – continues; the DoC released preliminary antidumping duties last month, while preliminary countervailing duties were released in February 2026. Final AD/CVD determinations are expected in the second half of 2026.
“The initiation of the AD/CVD investigation targeting Ethiopia represents a continuation of the protectionist trend that originated with China and has progressively expanded to encompass Southeast Asia and India,” said Moustafa Ramadan, head of PV Tech’s Market Research.
This course of action from US manufacturers against Ethiopia is the latest one in a series of solar AD/CVD cases and continues the never-ending game of tariff “whack-a-mole” (subscription required). The coalition mentioned that “similar trends have been observed in the Philippines, the Middle East, and countries in Africa, including Egypt and Nigeria.”
If the Department of Commerce initiates an investigation, this would be the fifth solar-related AD/CVD case, following Chinese c-Si PV products in 2012; Taiwan two years later; Vietnam, Malaysia, Thailand, and Cambodia in 2024 and the ongoing case looking into India, Indonesia and Laos.
The petition from the coalition of US-based manufacturers requests that the DoC initiate an inquiry within 30 days and issue an affirmative preliminary circumvention determination to provide immediate relief to domestic producers.

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Chinese researchers have found that massive photovoltaic deployment in the Taklamakan Desert could alter regional climate dynamics and worsen water stress in the already arid Tarim Basin, despite the area’s vast solar potential.
Satellite view of China’s Tarim Basin
Image: NASA, Wikimedia Commons, Public Domain
A research team is China has assessed the climatic impact of a huge PV deployment across the Tarim Basin’s Taklamakan Desert, which is one of the driest large deserts in the world, characterized by extremely low precipitation and very high evaporation rates. Water availability in the region depends heavily on meltwater from surrounding glaciers and seasonal snow, which feed the river systems of the Tarim Basin. However, as regional glaciers continue to retreat, the long-term reliability of this water supply is increasingly under pressure.
The researchers assumed a scenario in which most of the basin would be covered by utility-scale PV installations, with total electricity generation exceeding current global demand. Despite this extreme setup, their results indicate that even much smaller-scale deployments in the region could intensify existing water stress.
“The novelty of our approach lies in the use of a high-resolution of 9 km, process-based modeling framework that combines the regional climate system with dynamic vegetation cover,” said corresponding author Zhengyao Lu to pv magazine. “With that, we can explicitly resolve the complex surface-vegetation-atmosphere feedbacks at a regional scale in the Tarim Basin associated with massive PV deployment.”
“The most striking finding is that large-scale high-efficiency PV deployment in the Taklamakan Desert could intensify regional water stress, particularly in the populated areas along the desert edges,” the researcher added. “We are currently working on a new paper focusing on the interactions of wind and solar energy deployment through local climate-ecosystem feedbacks in the same study region.”
Image: Tarim University, Science Bulletin, CC BY 4.0
For their assessment, the research group used four climate datasets and one vegetation dataset covering the period 2016–2020: CN05.1 and CRU TS4.05 (Climatic Research Unit Time-Series version 4.05) for temperature and precipitation; the Global Precipitation Climatology Centre (GPCC) dataset to evaluate precipitation patterns; the ERA5 reanalysis from the European Centre for Medium-Range Weather Forecasts (ECMWF) to provide the primary atmospheric forcing data; and the Global Land Surface Satellite (GLASS) Leaf Area Index (LAI) product to characterize vegetation cover and plant dynamics.
They also employed two main numerical models: the Weather Research and Forecasting (WRF) model to simulate regional climate processes, and the Lund–Potsdam–Jena General Ecosystem Simulator (LPJ-GUESS) to represent vegetation dynamics and ecosystem responses.
Within this framework, WRF simulated key climate variables across the Tarim Basin, including temperature, precipitation, wind fields, runoff, and soil moisture. These outputs were then used to drive LPJ-GUESS, which simulated vegetation cover, LAI, and ecosystem responses to changing environmental conditions. The resulting vegetation changes were subsequently fed back into WRF, enabling the model to capture how shifts in plant cover further influence local climate and hydrological processes.
This coupled modeling approach allowed the researchers to assess both the direct climatic effects of PV installations and the additional indirect impacts mediated through vegetation–climate feedbacks.
 
Image: Tarim University, Science Bulletin, CC BY 4.0
The simulations assumed that the entire Tarim Basin was covered with PV panels, excluding legally protected areas, forested land, and terrain with slopes steeper than 30 degrees. To evaluate the climatic impacts of large-scale solar deployment, the researchers defined six effective albedo scenarios representing different levels of sunlight reflection and energy conversion by PV installations.
These scenarios included a control case without PV deployment (Ctrl); a present-day PV case with an effective albedo of 0.1925 and an estimated conversion efficiency of around 15% (S19); a future high-efficiency scenario with an effective albedo of 0.335 and roughly 30% efficiency (S335); two extreme high-efficiency cases with effective albedos of 0.62 and 0.905, corresponding to approximately 60% (S62) and 90% (S905) conversion efficiency; and an extreme low-albedo “black panel” scenario with an effective albedo of 0.05 and around 5% efficiency (S05).
The researchers found that the higher-efficiency PV scenarios, including the more realistic future case S335 as well as the extreme S62 and S905 scenarios, reflected more incoming solar radiation and reduced surface heating inside the basin. According to the simulations, this produced surface cooling of up to 1.5 C across the desert region.
The cooling effect weakened moisture transport into the basin, enhanced downward air movement, and stabilized the lower atmosphere, ultimately suppressing rainfall formation. Reduced precipitation subsequently led to declines in vegetation cover and Leaf Area Index (LAI), particularly around the basin margins. As vegetation cover decreased, evapotranspiration and low-level cloud formation also weakened, further reducing atmospheric moisture availability and reinforcing the decline in rainfall.
“We find that large-scale PV installations may significantly reduce water resources in populated areas, with over 30% reductions in runoff, precipitation, and aridity index, alongside an 8.5% decline in soil moisture,” the academics. “These results highlight the critical need to incorporate vegetation feedback in future studies to fully evaluate PV’s hydrological impacts and stress the importance of careful planning to mitigate environmental risks associated with large-scale solar projects in Northwest China.”
They added future studies should further investigate the hydrological effects of large-scale PV deployment and emphasized the need for careful project planning to minimize potential environmental impacts associated with utility-scale solar development in Northwest China.
Their findings were published in “Large-scale photovoltaic deployment in the Taklamakan Desert could intensify regional water stress” in Science Bulletin. Researchers from China’s Tarim University, Xiamen University, Beijing Normal University, Tsinghua University, the Chinese Academy of Sciences, the University of Chinese Academy of Sciences, Sweden’s Lund University, the University of Gothenburg, and Denmark’s University of Copenhagen have participated in the research.
Another recent research from China assessed the impact of using up to 50% of the Sahara desert for the deployment of large scale solar power plants and found these may impact the global cloud cover through disturbed atmospheric teleconnections. This, in turn, would impact solar power generation itself in North Africa, Southern Europe, the Southern Arabian Peninsula, India, North Asia, and even Eastern Australia.
 
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CIP’s Perigus kicks off solar farm consultation in Nottinghamshire  Renewables Now
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Published on 05/13/2026 at 09:13 am EDT
Introduction
Recently, the United States Department of Commerce (‘USDOC‘) preliminarily found that crystalline silicon photovoltaic cells, whether or not assembled into modules, (‘PUC/ subject goods‘) from India were sold, or likely to be sold, in the United States at less than fair value and that countervailable subsidies are being provided to producers and exporters of subject goods in India. USDOC assigned a dumping margin of 123.04% to Mundra Solar PV, Mundra Solar Energy, Kowa, Premier Energies, and all others.¹ Similarly, in the Countervailng Duty (CVD) investigation on subject goods, the USDOC assigned a subsidy rate of 125.87% to Mundra Solar Energy, Mundra Solar PV, and all others.²
These findings have direct relevance for Indian producers and exporters of subject goods. This article aims to analyze how the USDOC reached these outcomes, with focus on adverse-facts-available (‘AFA‘), critical circumstances, and the emerging issue of transnational subsidies linked to Chinese-origin inputs.
Anti-dumping determination
In the preliminary determination, the USDOC calculated a uniform 123.04% weighted-average dumping margin for all entities, including the mandatory respondents. This margin was assigned using AFA as the USDOC determined that the companies did not act to the best of their ability to comply with the USDOC’s requests for information. 
USDOC first selected Mundra Solar PV and Mundra Solar Energy as mandatory respondents. Both companies filed a Section A response but later withdrew from the investigation. USDOC then selected Kowa and Premier Energies as additional mandatory respondents. Kowa informed USDOC that it would not participate, and Premier Energies also withdrew.
This sequence shaped the entire determination. USDOC did not have complete home market sales data, US sales data, or cost of production data. It therefore concluded that necessary information was missing and that the respondents had withheld requested information, failed to provide it within the prescribed deadlines, and significantly impeded the investigation. On this basis, USDOC applied AFA under Section 776 of the Tariff Act of 1930.
The resulting dumping margin was therefore not a company-specific margin calculated from verified transaction data. It was a petition-based AFA margin. For Indian exporters, the finding shows the risk of non-participation in US Anti-Dumping proceedings. A decision not to participate may leave USDOC with no other option and allow a petition-based rate to define the market position of both selected and non-selected exporters.
CVD determination
The CVD preliminary determination has a different structure from the anti-dumping determination. USDOC examined several categories of programs including Production Linked Incentive schemes, export schemes, tax programs, SEZ-related benefits, grants, loans, state-level incentives, alleged purchases for more than adequate remuneration, and alleged transnational subsidies linked to Chinese-origin inputs.
However, the process again turned on the conduct of the mandatory respondents. USDOC selected Mundra Solar Energy and Mundra Solar PV as mandatory respondents. The Government of India (‘GOI‘) and Government of China (‘GOC‘) filed responses. Mundra Solar Energy and Mundra Solar PV filed a response, but USDOC recorded that the response was incomplete. Both companies later withdrew from the proceeding. USDOC therefore did not have company-specific information to test actual use, benefit, attribution, or cross-owned entity issues.
This gap affected the entire subsidy analysis. USDOC applied AFA to the mandatory respondents and treated several programs as used and beneficial to them. USDOC also relied on facts available where it considered the GOI’s program-level information to be insufficient to determine financial contribution or specificity. The result was a cumulative subsidy rate applying AFA for all producers/ exporters under Section 776 of the Tariff Act of 1930.
Transnational subsidies: Chinese inputs and an emerging CVD theory
USDOC did not limit its enquiry to subsidies granted by the GOI or state governments in India. It also examined whether the GOC provided Chinese-origin inputs to Indian producers for less than adequate remuneration. The inputs examined included polysilicon, silicon wafers, silver paste, solar glass, aluminium solar frames and junction boxes.
USDOC’s analysis proceeded in two stages. First, it asked whether Chinese producers of these inputs could be treated as ‘authorities’ for purposes of the US CVD law. For this, USDOC sought information from the GOC on ownership structure, registration documents, ultimate state ownership, articles of incorporation, company by-laws, annual reports, articles of association, and the role of officials or committees in the management of input producers. USDOC relied on AFA and held that GOC could not verify or provide information on program related to exporters or producers of the subject goods originating in India.
Second, USDOC relied on record material placed by the petitioner. This included information on China’s share in global production of key solar inputs, Chinese five-year plans, alleged state control over input producers, export data showing price differences, and earlier CVD findings in solar cell investigations involving Cambodia, Malaysia, Thailand and Vietnam. For example, for polysilicon, USDOC referred to petitioner’s information that China produced 93% of the world’s solar-grade polysilicon.
The legal difficulty is that the alleged subsidizing government was not India, while the investigated producers/exporters were Indian. This is where the SCM Agreement becomes important. Article 1.1 of the SCM Agreement defines subsidy by reference to a financial contribution by a government or public body conferring a benefit. Article 2 requires specificity to an enterprise, industry, or group of enterprises or industries within the jurisdiction of the granting authority.
The GOC’s response challenged USDOC’s legal basis. It argued that transnational subsidies do not constitute a financial contribution under Article 1.1 of the SCM Agreement, and that countervailing such subsidies violates the jurisdictional requirement under Article 2. It also argued that neither WTO rules nor US law permit countervailing investigation of transnational subsidies. It also argued that prior South-East Asia findings on subject goods cannot establish the existence of program in the India case. On merits, it disputed public body status, specificity, benefit and pass-through. It argued that any subsidy to a Chinese input producer cannot be presumed to pass through to an Indian producer buying the input in a market transaction.
While the GOC’s arguments are primarily on legal structure and pass-through, the USDOC’s reasoning is more dependent on missing information and AFA. Its approach is that the absence of complete GOC and respondent data prevented a full test of ownership, control, pricing and benefit. For Indian producers of subject goods, the risk is clear. Even if the subsidy is not granted by India, sourcing from China can become a CVD issue if the record does not establish arm’s-length pricing, supplier identity, and absence of benefit transmission.
Critical circumstances: Retroactive duty exposure
Critical circumstances is a finding that allows US authorities to apply anti-dumping or CVD measures retroactively to recent imports, rather than only to imports made after the preliminary determination is published. In order to ascertain critical circumstances, USDOC normally compares the import volumes of the subject merchandise for at least three months immediately preceding the filing of the petition to a comparable period of at least three months following the filing of the petition to ascertain the increase in imports. Such imports must increase by at least 15 percent during the comparison period to be considered massive. 
In simple terms, if USDOC believes that there is massive surge in imports of goods into the US after becoming aware that duties were likely, it may permit duties to apply to unliquidated entries made up to 90 days before publication of the preliminary determination. 
Since no mandatory respondents were participating, USDOC did not request monthly shipment data from any company and proceeded on the data available.
The USDOC preliminarily found that critical circumstances exist for mandatory respondents, but not for all other exporters and producers from India. Therefore, it directed that suspension of liquidation would apply to unliquidated entries from these identified producers/exporters entered up to 90 days before publication of the preliminary determination. This will have a significant implication for the mandatory exporters/producers.
Context of India’s solar industry and export trajectory
The US proceedings also sit against India’s own solar trade remedy context. In September 2025, the Directorate General of Trade Remedies (‘DGTR‘) of India issued final findings in the anti-dumping investigation on imports of solar cells, whether or not assembled in modules or panels, from China. DGTR recommended anti-dumping duty for three years. 
This explains the commercial position of Indian manufacturers. They face price competition from Chinese-origin products in India. At the same time, their exports to the U.S. are being examined partly through the lens of Chinese-origin input dependence. The DGTR recommendation was faced with legal and policy friction before translating into non-imposition of anti-dumping duty. For Indian producers, this creates a policy tension. Domestic protection, export growth, and input sourcing cannot be viewed separately.
Way forward for Indian producers of subject goods
The preliminary determinations show that Indian producers of subject goods must treat proceedings as market-access issues, not only as legal proceedings. Participation strategy is central. Where selected exporters do not place sales, cost, subsidy and sourcing data on record, USDOC may rely on AFA. This can affect not only the selected companies, but also the all-others rate. 
Indian exporters should therefore maintain investigation-ready records. This includes transaction-level sales data, cost data, subsidy usage records, related-party information, supplier details and input pricing evidence. Sourcing from China also requires closer review. Considering USDOC’s transnational subsidy approach, exporters may need to demonstrate supplier identity, ownership, arm’s-length pricing and absence of pass-through of any alleged benefit. 
For India, the outcome could catalyze a more integrated, less import-dependent solar value chain, positioning it as a resilient global player even as it navigates protectionist headwinds in key export destinations.
Footnotes
1. https://www.govinfo.gov/content/pkg/FR-2026-04-28/pdf/2026-08194.pdf
2. https://www.govinfo.gov/content/pkg/FR-2026-02-26/pdf/2026-03895.pdf
Arpit Mehra Lakshmikumaran & Sridharan
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Tel: 112619 2243
Fax: 112619 7578
E-mail: arnab.bhattacharya@lakshmisri.com
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US solar manufacturer T1 Energy has registered a record quarterly net income and adjusted earnings before interest, taxes, depreciation, and amortisation (EBITDA) in the first quarter of 2026.
This was achieved through a higher-than-forecasted module production, which reached 683.3MW, and sales in the first three months of the year. In April, the manufacturer produced modules at an annualised rate of 3.4GW, which is in line with the 3GW of contracts executed in 2026.
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Unlike in 2025, when the company started the first quarter with a net loss of US$6.2 million, T1 Energy registered a net income from continuing operations of US$3.9 million. Similarly, the company registered an adjusted EBITDA of US$9.1 million in Q1 2026 compared with a US$4 million loss in the same period in 2025.
Moreover, the company reiterated its commitment to US domestic manufacturing—which will be a key topic at this year’s PV CellTech USA Conference in San Francisco—and its strategic alignment with key US policies. T1 Energy expects to be well-positioned for a potential ruling in the US Department of Commerce’s Section 232 investigation into polysilicon sourced from overseas manufacturers.
The company’s G2_Austin plant, which will produce tunnel oxide passivated contact (TOPCon) solar cells and at which construction began in December 2025, is proceeding on schedule with production set to begin in Q4 2026. Once fully operational, G2_Austin will have a 2.1GW annual nameplate capacity for solar cells and a total investment of over US$400 million.
Last month, the company completed an upsized public offering of US$160 million, which was originally set at US$120 million, with convertible senior notes due in 2031 and generated net proceeds of US174.7 million, which positioned the company to continue construction of the solar cell processing plant. T1 Energy added that it pursues a comprehensive financing solution with a significant debt component.
“Our team made excellent progress during the first quarter to advance our top priorities: operate profitably at G1_Dallas, fund and build G2_Austin, and establish T1 as an integrated, homegrown US solar and storage powerhouse supporting domestic energy and hyperscaler development,” said Dan Barcelo, CEO and chairman of T1 Energy.
“As we look ahead, we are focused on hitting key construction milestones, targeting a comprehensive financing package for G2_Austin in the second quarter, building our offtake coverage through our developer customer base, and driving profitability as T1 grows,” added Barcelo.
A second phase would expand the annual nameplate capacity to 5.3GW, with a potential third phase extending manufacturing capacity up to 8GW on the existing leasehold.
“We believe we are positioned to flex capacity to develop up to three phases potentially totalling as many as 8GW on our existing leasehold,” wrote the company in its quarterly report.

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Gamuda Berhad Wins RM600 Million Australia Solar Project Contract  SolarQuarter
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A 200-kilometre urban road test of the Innoptus Solar Team’s Infinite Apollo served as final validation for Longi’s high-efficiency technology before the American Solar Challenge in July.
Going back decades, the field of solar racing has served as the proving ground where module manufacturers test technologies in conditions that are simply too rough for the lab. Late last month, Belgium’s Innoptus Solar Team took their Infinite Apollo race car on a 200-kilometre tour of urban roads, with the back contact cells from Longi Green Energy Technology put to work in live traffic, shifting irradiance and the kind of everyday operating conditions a test rig cannot easily replicate.
Megawatt charging kicks into gear for Europe’s e-trucks
The route covered six locations across Belgium and was the last major outing before the American Solar Challenge in July, where the same vehicle and module package will compete. Innoptus has spent ten months developing the car, which has clocked several thousand kilometres on the upgraded module and battery configuration in advance of the road test. Longi confirmed in March that it would equip the Apollo with its back contact technology and vehicle-integrated photovoltaic solutions for the American campaign.
Longi has spent the past five years pushing back contact architecture as its lead candidate for the next generation of high-efficiency cells, breaking the photovoltaic cell conversion efficiency record 23 times since 2021 according to the company. This includes a 28.13 percent figure for HIBC cells, certified by ISFH in Germany earlier this year, and a 26.4 percent module efficiency record using the same technology, certified by NLR in the United States. A separate 34.85 percent result was achieved last year for crystalline silicon-perovskite tandem cells, certified by NREL.
Fraunhofer-led project scales up charging for heavy-duty transport
The Belgian project also features the Antwerp-based industrial minerals group Sibelco, which supplies the high-purity quartz sand that goes into the cells used in the Apollo. The arrangement gives Longi a fully traceable material chain for the racing programme – from feedstock through to the vehicle-integrated modules that wrap the bodywork. Over the full 200 kilometres, the car kept a steady energy output as light conditions changed from site to site, the team reported.
The harder test will come in the factory rather than on the road, as TOPCon and HJT lines scale up in the next two to three years and the efficiency gap narrows. Until then, the Apollo and its American successor stand as a visible, rolling demonstration of what back contact cells can deliver in real-world conditions. (TF)
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By Moncef Krarti, University of Colorado Boulder
Somewhere between 5% and 7% of U.S. households have rooftop solar panels. Many more Americans want them, but high costs, building locations and landlord restrictions are key obstacles.
As someone who has designed and evaluated a wide range of building energy efficiency technologies, including integrated photovoltaic systems, I know that other options are available elsewhere in the world – and are becoming available in the U.S. Plug-in solar systems, also referred to as balcony solar systems, are alternatives to rooftop panels that still generate electricity from sunlight, but without complex and expensive installations.
Plug-in solar systems are designed to be used without requiring specialized technicians, construction permits or permission from electricity utility companies. A typical system consists of small photovoltaic panels that can be placed on a balcony, in a backyard or on a deck or roof area. They are connected to the home’s electrical system by simply plugging them into a regular power outlet.
In Europe, systems like this have been legal for more than a decade. They are wildly popular, especially for renters who do not have permission to install permanent solar panels on their buildings.
In Germany, the introduction of balcony solar raised the share of households with solar panels to about 10%.
Germans can buy plug-in solar kits in local retail stores and set them up quickly at home, with no help or oversight from technicians or utility companies. Estimates find that with current electricity prices in Germany, the systems generate enough power to pay for themselves in less than three years.
In the U.S., the main barrier to widespread availability and adoption of plug-in solar systems is that current laws and regulations do not distinguish them from larger rooftop panel systems.
In most cases, solar panels on buildings that are connected to the power grid must be installed by professionals, because they typically require additional equipment that prevents too much of the home-generated power from entering the grid. This process also requires a permit from a state or local government.
For balcony solar systems, the grid-protection equipment is built in to what consumers buy at the store. But in most states, the laws don’t recognize a difference and still require permits and professional installation for any solar panels at all.
However, in 2025, Utah passed a law that removes those requirements for plug-in solar panel systems that generate less than 1,200 watts of power. Maine has enacted a similar law, and one in Colorado awaits the governor’s signature. Both are slated to take effect at different points in 2026. The Vermont Senate passed one too, and the state’s General Assembly is considering it now. And lawmakers in 25 other states are considering similar legislation.
In addition, in early 2026, UL Solutions, an independent safety certification company, announced a new standard for plug-in solar systems in the U.S., which can help consumers feel confident they are buying something that is safe for them to use in their homes.
The potential benefits of balcony solar systems vary primarily with the local cost of electricity. Buying these systems can cost between $1,200 and $2,000, but they can generate enough power to save several hundred dollars in electric bills each year.
They can’t power a whole home, but they can power relatively low loads, like refrigerators, LED lights, laptop computers, phone chargers, televisions and fans, even when a grid power outage occurs.
Depending on their configurations, balcony solar systems can offer additional benefits. Mounting them to movable bases that track the Sun’s path through the sky can boost power generation. Mounting the panels on overhangs can create shade, reducing the need for air conditioning, especially in hot climates.
Adding battery storage to balcony solar systems can also help households store extra energy from the daytime and use it at night, further lowering their utility bills, though buying batteries would raise the costs.
I expect U.S. demand for balcony solar systems to be significant, especially in places with lots of sunlight and high electricity prices. Householders will still need to select their equipment and its location carefully to maximize their power generation and cost savings.
Moncef Krarti is a professor of civil, environmental and architectural engineering at the University of Colorado Boulder.
This article is republished from The Conversation under a Creative Commons license. Read the original article. Banner photo: Solar panels on a balcony in Germany (iStock image). 
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VSB gets go-ahead for 36-MW solar project in Sicily  Renewables Now
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5 Solar Energy Stocks with Strong Order Book  Equitymaster
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IPE RA magazine May/June 2026
By IPE staff2026-05-13T13:20:00+01:00
Power company Fuse Energy has purchased a solar farm from the UK’s Caerphilly County Borough Council, which the company expects will power up to 6,000 homes as well as accelerate grid flexibility. 
The project is expected to connect to the grid in December 2026, Fuse said in a statement. No figure was given for the transaction.
Amanda McConnell, Caerphilly Council’s cabinet member for climate change, said the move represented an important step in tackling the climate emergency as well as increasing renewable energy in Caerphilly.
“The Cwm Ifor Solar Farm could power around 6,000 homes with clean electricity, while supporting a more flexible and resilient energy system,” McConnell said in a statement.
The project marks a significant step in scaling Fuse Energy’s renewable generation portfolio and advancing a lower-cost energy system in the UK, Fuse said.
The acquisition expands the company’s growing renewable portfolio with a current 1GW pipeline across solar and wind projects. Fuse Energy plans to develop Cwm Ifor using in-house engineering, procurement and construction.
A previous solar project was recently completed by the company at a 30% lower cost per MW peak than the industry average.
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A trout farming operation in eastern France is demonstrating how photovoltaic infrastructure can address operational, environmental, and energy challenges in aquaculture. At Pisciculture Beuque, solar canopies installed above fish basins combine physical protection with on-site renewable energy generation, supporting long-term productivity and cost stability.
The project integrates nearly 1,200 back contact photovoltaic modules from LONGi, with a total installed capacity of approximately 500 kWp. Implemented in collaboration with POwR Connect, a French photovoltaic installer and EPC, the system is designed to cover a significant share of the site’s annual electricity demand of around 120,000 kWh, with the potential to transition toward energy-positive operation following the planned addition of storage.
 
PV as physical barrier addresses core challenges in aquaculture
Fish farming operations face increasing pressure from environmental exposure, rising energy costs, and biological risks. At Pisciculture Beuque, predation by fish-eating birds has been a persistent issue, affecting both stock levels and sanitary conditions.
The photovoltaic canopy system creates a physical barrier that limits bird access to the basins, reducing direct losses and lowering the risk of disease transmission. At the same time, the shaded environment contributes to more stable water temperatures and reduces stress for the fish, supporting healthier growth conditions.
“Predation from birds is a major challenge for us, both economically and in terms of sanitary risks,” said Pascal Beuque, owner of the fish farm. “With this solution, we are able to protect the basins while also addressing our energy needs.”
 
Integrated energy generation and operational efficiency
The installation uses high-performance back contact modules from LONGi’s Hi-MO X10 series. By relocating electrical contacts to the rear side of the cell, the design increases the active surface area available for light absorption, supporting high efficiency and stable performance.
The project is coupled with power optimizers and inverters, with a total capacity of 400 kVA. This configuration supports optimized system performance, including under partial shading conditions inherent to canopy structures.
The system supplies electricity to key operational processes, including basin aeration, water circulation, cold storage, and site infrastructure. Production is split between self-consumption and grid export, providing both cost savings and additional revenue potential.
 
Environmental impact and working conditions improve alongside energy cost stability
Beyond energy generation, the canopy structure contributes to environmental management. By limiting direct solar exposure, it reduces the temperature of water discharged from the facility, helping to mitigate impacts on surrounding ecosystems.
The installation also improves working conditions on site. Staff are protected from rain, snow, and direct sunlight, enabling safer and more consistent operations throughout the year.
Initial considerations around the project focused on financial feasibility. According to the operator, similar installations in other agricultural sectors demonstrated that photovoltaic canopies could support both operational needs and economic performance.
“It initially seemed like an investment that would be difficult to justify,” Beuque said. “But when we looked at the long-term energy savings and the added operational security, it became a viable option.”
The system is expected to reduce energy costs significantly and provide protection against electricity price volatility. With the planned integration of storage, the site aims to achieve a high degree of energy autonomy.
“Applications like Pisciculture Beuque highlight how photovoltaic infrastructure can be adapted to specific industry requirements. By combining energy generation with functional site benefits, these systems contribute to more stable and efficient operations in sectors such as aquaculture,” said Alain Kruy, Product Solution Manager at LONGi for France.
 
PV canopies provide a practical pathway to more resilient and energy-independent aquaculture operations
The project was developed as an integrated solution, combining structural design and photovoltaic deployment. Installation, maintenance, and system monitoring are managed by Héliophoton, ensuring long-term performance and operational reliability.
Implementation was carried out in collaboration with POwR Connect, responsible for project delivery. Close coordination between the fish farm operator, the installation partner, and technology providers supported timely completion, including advisory, logistics, and system integration.
The Pisciculture Beuque installation illustrates how photovoltaic infrastructure can extend beyond energy generation to address sector-specific challenges. By combining biological protection, environmental management, and on-site power production, the project demonstrates a practical approach to improving resilience in aquaculture operations.
With increasing pressure on food production systems to reduce environmental impact while maintaining efficiency, integrated solutions of this type are expected to play a growing role across agricultural sectors.

Weekly editor’s choice.

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PM Modi Calls for Accelerated Solar Irrigation Deployment to Reduce Diesel Dependence and Strengthen India’s Energy Resilience  SolarQuarter
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India Plans China-Style Super Grid To Support 1,800 GW Renewable Energy Goal By 2050  SolarQuarter
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Solex Energy Posts 247% Q4 Revenue Growth Driven by Rising Demand for High-Efficiency Solar Modules  SolarQuarter
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Natural Forces Solar website
Solar panels installed at Pictou Landing First Nation are among the projects by Natural Forces Solar, which has proposed projects for Colchester County.

Natural Forces Solar website
Solar panels installed at Pictou Landing First Nation are among the projects by Natural Forces Solar, which has proposed projects for Colchester County.
Colchester Council moved to write a letter of support for Natural Forces Solar (NFS) which pitched three different solar farm developments.
Those farms are the Glenholme Solar Project, the Lower Harmony Solar Project (in Greenfield), and the Newton Mills Solar Project.
The combined capacity of all projects would be up to 16 megawatts. For reference, one megawatt refers to one million watts of electricity produced by a power plant that is suitable for delivery to the electrical grid. This would be enough electricity to power a potential 2,600 homes. 
NFS hopes to begin construction on the Newton Mills and Lower Harmony Solar Projects in late 2026-27, the Glenholme Solar Project by 2027.
“The intention, of course, is that local businesses and/or households would receive bill savings from this project,” said project development manager Mitchell van Oosten. 
“It’s maybe — for this question in particular — important to stress that this system is connected to distribution lines. Those are the relatively low-voltage lines. That means that the electricity, by design of the electrical system, has to be consumed local to the project.”
On the lifespan of the solar farms, van Oosten claimed they have a 15-year product warranty and a 30-year power-output guarantee. 
“So after 30 years, the panels will still be producing 87 per cent of their initial rated capacity. The most likely scenario is that actually we would just leave them and allow them to carry on producing electricity at that stage, unless, of course, in the next 30 years there’s some extraordinary breakthrough in technology and it makes sense to replace them at that point,” he said. 
When they reach the end of their natural lives, the panels will be recycled as best as possible with the future technology available, van Oosen claimed. He then pointed out that the panels are made up mostly of glass and aluminium, which are easy to recycle. 
Regarding maintenance, van Oosten said that they would make two to six trips a year to make sure everything is running smoothly. They would also need to manage vegetation.
“Of course, we need to keep the grass down. One option may be to hire a local grass-cutting company, but our preferred option is to get a shepherd with some sheep to come out and keep the grass down that way,” he said. 
Some of their previous builds include the solar panels at the North Shore Recreation Centre in Tatamagouche, the solar panels at the West Colchester United Arena in Debert, and the 20-acre solar farm for Oxford Frozen Foods, one of the biggest projects in Nova Scotia according to van Oosten.
During Q&A District 5 Coun. Tim Johnson asked how the land would be acquired, to which van Oosten replied it would be leased from the landowners, something he said they’d never had a problem with before. 
“That process looks like finding a viable property online and working out who owns it and going to the front door and asking them if they’d like to lease their land. I’ve done that myself in all cases. We offer a rate that we think is significantly above what somebody would earn from, for example, an agricultural lease. Often they might see their property value returned to them in, say, under five years, something like that,” he said. 
 
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COUNCILLORS have unanimously refused a Perthshire solar farm development the size of 100 football pitches on prime agricultural land, stressing the importance of food security.
Urging Perth and Kinross councillors to refuse the latest green energy application, local councillor Michelle Frampton told councillors “Almond and Earn has reached its limit” and declared “enough is enough”.
The proposal – submitted by Gray Planning and Development on behalf of NS Solar Kinnon Park – received 316 letters of objection and three letters of support.
On Wednesday, May 13 Perth and Kinross Council’s Planning and Placemaking Committee met to consider the application.
Solar farm proposal at Kinnon Park, Methven (Image: Perth and Kinross Council)
NS Solar Kinnon Park submitted plans to develop a solar farm and battery energy storage system at Kinnon Park Park Farm, 700m southwest of Methven on 81 hectares of land within a 99-hectare site. Presenting the application to councillors at Wednesday’s meeting, PKC’s Major Applications and Enforcement team leader Sean Panton said the development site was equivalent in size to 100 football pitches.
He outlined the three reasons for planners’ recommendation of refusal were:
Ground-mounted 3m high panels were proposed in rows with 232 inverters and 20 transformers positioned around the solar farm, along with a number of substations.
The 316 objectors – including Methven and District Community Council – listed concerns which included: its visual impact; flood risk; excessive height; inappropriate land use; loss of open space; light pollution; loss of trees, sunlight and daylight; noise pollution; over-intensive development; overlooking; road safety and the impact on local biodiversity.
READ MORE: How Scotland’s energy bills subsidise lairds’ wind farm jackpots
National Gas Transmissions – which operates a high-pressure gas pipeline that runs through the site – submitted a holding objection that the development must not proceed without further assessment being undertaken by the Asset Protection Team.
A number of deputations were made to Wednesday’s meeting of the Planning and Placemaking Committee including one from Almond and Earn ward councillor Michelle Frampton who urged councillors not to “destroy” food security.
The SNP councillor said: “In the current climate, it is very easy to let the ‘green’ label of a project act as a shield against scrutiny. But a project is not sustainable if it destroys the very foundations of our local environments and our food security.
“Planning is about balance. It is about the right development in the right location.”
She added: “This application seeks to build on prime agricultural land. This is not ‘marginal’ land, this is the high-quality soil that grows food for our tables. Once you cover prime earth with glass, steel and lithium-ion batteries, you are not just borrowing it for years, you are downgrading it.
“We are living in an era of global instability, where food security is becoming as critical as energy security. We cannot keep sacrificing our best fields for infrastructure that could and should be placed on brownfield sites.”
Cllr Frampton argued there was “a tipping point where a contribution becomes saturation”.
She said: “I understand the need for renewable energy. I agree that we must transition our grid. But Almond and Earn has already stepped up to the plate. Our ward is already home to a significant concentration of solar farms, battery storage sites and wind farms. We have done our bit; we have accepted our share of the national burden.
“But there is a tipping point where a contribution becomes saturation. Our ward is being viewed as an east target for developers.”
Cllr Frampton added: “A line needs to be drawn somewhere. We need to say enough is enough.
“I ask this committee to listen to the community. I ask that you recognise that Almond and Earn Ward has reached its limit.”
The applicant’s planning agent Cameron Greig from Morton Fraser Macroberts expressed concern the council’s approach was “legally flawed”.
He pointed to two policies in Scotland’s National Planning Framework 4 (NPF4) which he said “superseded” PKC’s local development plan policies. He pointed to policy five which supports renewable energy development.
However, the policy says development can only be allowed on prime agricultural land if is “essential infrastructure and there is a specific locational need and no other suitable site”.
Greig also pointed to NPF4 policy 11 which states: “Development proposals for all forms of renewable, low-carbon and zero emissions technologies will be supported.”
READ MORE: Popular Scottish bar and restaurant hits out over ‘fried rat’ rumours
Neil Gray from Gray Planning and Development said the recommended refusal by planning officers was a “planning balance judgement” and “elected members could make a different planning balance judgement”.
He argued the development would make a “subtantial contribution towards Net Zero” and would address a “national crisis” and the need to move away from fossil fuels.
Having heard both sides, councillors unanimously voted to refuse the application.
The proposal was moved for refusal by local Conservative Almond and Earn ward councillor David Illingworth.
Conservative councillor Bob Brawn (Image: Angus Forbes)
It was seconded by Conservative Blairgowrie and Glens ward councillor Bob Brawn who argued there were now “sufficient” renewable energy projects – and they could now be “far more selective” about where they are developed – but prime agricultural land was “finite”.
He added: “If you go on as we are, without being selective, there could be loads of renewable energy but we don’t have any land left to grow food. Food security is important.”
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Published: May 13, 2026
SAVAGE, MINNESOTA – Multiple fire departments responded to a second-alarm house fire in Savage late Tuesday morning, May 12, 2026, after reports of smoke and flames coming from solar panels mounted on the roof of a home.
According to an incident report from Savage officials and the Savage Fire Department, Savage Fire and Mdewakanton Fire were dispatched at approximately 11:35 a.m. to a residence in the 12000 block of Huntington Avenue for reports of smoke and fire coming from a solar panel system on the roof of the home. While crews were responding, dispatch updated firefighters that smoke and visible flames were coming from the roof area, possibly involving the solar panels.
Savage Chief 2 arrived on scene and reported a small single-story split-level home with an exterior fire involving the solar panel system on the roof. Fire officials said a 360-degree assessment confirmed a working fire in the solar panels on the Charlie side of the structure, and crews initially pursued an offensive strategy, attacking the fire from the exterior. The incident was upgraded to a second alarm around 11:43 a.m., bringing in mutual aid from Shakopee Fire, Prior Lake Fire, and Burnsville Fire. However, as crews quickly gained control of the situation, incoming mutual aid units were advised to reduce their response speeds, and Burnsville units were later canceled at around 11:54 a.m.
Savage Engine 1 was assigned to stretch a hose line to the Charlie side of the residence and begin exterior fire attack operations on the roof-mounted solar panels. Firefighters also confirmed that the home’s solar panel disconnects on the Delta side of the residence had been shut down to reduce electrical hazards during firefighting operations.
According to the incident report, crews knocked down the exterior fire relatively quickly before transitioning to the attic to check for fire extension. Firefighters used positive-pressure ventilation fans to help keep smoke from spreading into the residence while crews entered the attic. During the interior investigation, firefighters found charring and heat damage to the underside of the attic decking beneath the exterior fire, but no significant extension was found deeper into the attic space.
Prior Lake Engine 1 was brought forward from staging as an on-deck crew and later assisted Savage firefighters in the attic overhaul operation. Crews removed insulation around the charred areas and applied water to hotspots to ensure the fire was fully extinguished.
Excel Energy also responded to the scene and confirmed that power to the solar panels had been shut off. Utility crews worked with firefighters and the homeowner to secure the electrical connections to the residence.
Fire officials later determined the fire was under control, with all losses stopped. Remaining units from Savage, including Engine 1 and Ladder 1, along with Prior Lake Engine 1, stayed on scene for overhaul and cleanup operations.
The Savage Fire Marshal responded to investigate the incident and worked with the homeowner regarding the damaged solar panel system. Fire officials advised the homeowner to contact the solar panel supplier for maintenance and to arrange removal of the damaged panels to prevent further hazards.
No injuries were reported during the incident.
Rough location of the fire and the incident.
Written by: Will Wight
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MNRE Mandates 10-Year Product Warranty And 25-Year Performance Guarantee For Solar PV Modules  SolarQuarter
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German energy company RWE has commissioned its 273.6MW Emily Solar project in Illinois, taking the developer’s operating renewable energy portfolio in the state to 1GW. 
The Emily Solar project, located across Clark and Cumberland counties, marks the latest addition to RWE’s Illinois portfolio, which now comprises two solar plants and three wind projects.
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RWE has operated in Illinois for 15 years and has continued expanding its renewables footprint as utilities and corporate buyers increase demand for new generation capacity in the US Midwest. The company said the Emily Solar commissioning strengthens grid reliability while delivering “abundant, affordable energy” to consumers. 
Hanson Wood, chief development officer, RWE Americas, “As electricity demand continues to grow across Illinois, reaching 1GW of operating capacity in this state is an important milestone for RWE and for the communities we serve. Emily Solar shows how energy projects can deliver safe abundant, reliable power while creating jobs and providing tangible local benefits for Clark and Cumberland Counties.” 
RWE Americas, the US arm of RWE, operates a diversified portfolio of around 13GW of generation assets across 27 states, spanning solar, wind and battery storage technologies. 
Last year, RWE Clean Energy commissioned the 200MW Stoneridge Solar PV project in Texas, alongside a co-located 100MW/200MWh battery energy storage system (BESS), marking a key expansion of its US renewables portfolio. The project, located in Milam County, was completed by RWE’s US arm following construction works that concluded on site yesterday, according to the company. 

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Good afternoon, Chicago.
Plans for a massive solar farm in Will County once again got a no vote from the county’s Planning and Zoning Commission.
The commission’s 4-1 vote against Earthrise Energy’s plans for a 6,100-acre, 600-megawatt solar farm near Manhattan now goes to the Will County Board’s executive committee for review tomorrow. The board is expected to vote on the project May 21.
Here’s what else is happening today. And remember, for the latest breaking news in Chicago, visit chicagotribune.com/latest-headlines and sign up to get our alerts on all your devices.
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Former mayoral candidate Paul Vallas is being fined $214,000 for violating campaign finance rules by accepting excessive contributions from people who were doing business with the city, the Chicago Board of Ethics announced yesterday. Read more here.
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The new location of Hollywood Casino Aurora is set to host a variety of live performances following its grand opening next month. Read more here.
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The Bears will learn their full 2026 schedule tomorrow for their defense of the NFC North title. Foremost on the minds of many fans is how the Bears will get to the quarterback after not signing or drafting any edge rushers. Brad Biggs’ weekly Bears mailbag begins there. Read more here.
More top sports stories:
Any Samara Joy show is a special one, and this one was no exception. Joined by her septet and the Chicago Symphony Orchestra, led by conductor Steven Reineke, Joy performed a medley of tunes — her own originals as well as standards and more obscure selections within the vocal jazz canon — to rapturous applause. Read more here.
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Annual electric power generated from solar will surpass that of coal in Texas for the first time in 2026, according to the U.S. Energy Information Administration's latest Short-Term Energy Outlook.
By the numbers:
Utility-scale solar generation is expected to reach 78 billion kilowatt-hours in the Electric Reliability Council of Texas grid in 2026, compared to 60 billion kilowatt-hours from coal.
Solar generation is expected to climb to 99 billion kilowatt-hours in 2027. Coal power generation is expected to increase at a much lower rate, up to 66 billion kilowatt-hours.
Big picture view:
While solar power generation is increasing in the Lone Star State, it still pales in comparison to the energy produced by natural gas, which accounts for around 44% of all electricity generation in the state.
Still, solar's footprint is increasing and has climbed from 4% of all energy generated in Texas in 2021 to 12% in 2025. Coal's share of energy generation has dropped from 19% to 13% over the same time period.
The Source: Information in this article comes from the U.S. Energy Information Administration’s Short-Term Energy Outlook.
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Sigenergy India Launches India’s First 500 kW Utility Inverter, Bets Big on Hybrid Solar Shift Photograph: (Saur Energy)
Energy technology company Sigenergy India has unveiled what it claims is India’s first 500 kW utility-scale inverter, as the company sharpens its focus on hybrid inverters, battery storage and AI-driven energy management solutions for the Indian solar market. 
Speaking at an industry exhibition, Abhilash Borana, CEO of Sigenergy, said the company is launching a wide range of residential, commercial and utility-scale products in India, including microinverters, hybrid inverters, battery systems and utility-scale PV inverter solutions. 
The company launched commercial hybrid inverters ranging from 50 kW to 125 kW, along with commercial and industrial PV inverters from 50 kW to 166 kW. It also introduced 500 kW, 400 kW and 370 kW utility inverter variants for large-scale solar projects. 
“We are the first one launching a 500-kilowatt utility inverter with 1,000 volts globally, and of course, the first one launching in the Indian market as well,” Borana said.  According to the company, the launch is part of a broader strategy to offer an integrated energy ecosystem across residential, commercial and utility-scale segments.
“How I describe Sigenergy is from one panel to any megawatt or gigawatt, Sigenergy will take care,” Borana said. 
Borana said India’s solar market, which has largely relied on string inverters, is now moving toward hybrid systems as renewable energy penetration increases and grid balancing becomes more critical.
“India market predominantly is a string inverter market, but a string inverter is good for solar generation. Now the market is shifting because the grid is not able to take all the excess energy,” he said.  He added that hybrid inverters paired with battery storage systems can help store excess daytime solar power and improve renewable energy utilisation during non-solar hours.
“The battery is solving a lot of things. Whenever you have excess electricity, it is stored in the battery, and then at night you can use the solar energy generated during the day,” Borana said.  Sigenergy is also positioning artificial intelligence and software-driven energy optimisation as key differentiators in the increasingly competitive inverter market.
“Before everything was hardware, but nowadays hardware is 30 percent of the piece. Mainly it is the software,” Borana said, adding that the company’s AI-enabled systems automate energy management and optimise solar consumption, storage and grid interaction. 
The company further revealed plans to introduce DC-coupled utility-scale storage solutions in India, claiming it would be among the first firms to offer such systems in the domestic market. On localisation plans, Borana said the company intends to begin manufacturing products in India starting next year. “You will see next year Sigenergy products made in India,” he said, adding that the company is in discussions with multiple government bodies and organisations regarding local manufacturing initiatives. 
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With renewables meeting rising power demand and shaping export competitiveness, India’s clean energy strategy is becoming central to industrial policy. 
India’s renewable energy sector saw a major surge in investment momentum last year, with deal values rising more than five-fold to nearly $2 billion, reflecting growing confidence in the country’s clean energy roadmap.
Addressing the CII Annual Business Summit 2026, Union Minister for New and Renewable Energy Pralhad Joshi said India is entering the next phase of its energy transition, which will focus on integrating renewable power generation with storage systems and modern transmission infrastructure. He noted that achieving the country’s 500 GW non-fossil fuel capacity target by 2030 will depend on stronger grid resilience, battery storage deployment, hybrid renewable projects, offshore wind development and round-the-clock clean power solutions.
The minister highlighted that clean energy policy is increasingly shaping industrial competitiveness and global trade participation as climate-linked regulations tighten worldwide. According to estimates from the International Energy Agency, India recorded the fastest renewable energy capacity growth among major economies in 2025 and now ranks as the world’s second-largest solar market and third in overall renewable capacity.
Over the past decade, India’s non-fossil fuel capacity expanded from 81 GW to 288 GW. Solar capacity alone jumped from 2.8 GW to 155 GW, while wind power installations rose to 56.4 GW. Domestic manufacturing capabilities have also strengthened significantly, with solar module production capacity increasing to 172 GW and solar cell capacity reaching 29 GW.
Renewable energy is playing a growing role in meeting rising electricity demand, contributing nearly one-third of India’s record peak demand of 256 GW last month. Despite declining global renewable investments, India continues to attract strong capital inflows supported by policy reforms, manufacturing incentives and tax rationalisation measures.
Joshi added that affordable clean energy will increasingly determine competitiveness across sectors such as steel, automotive, chemicals and textiles, while green hydrogen and renewable-powered industrial systems are expected to drive future export growth.

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A Nevada utility just told 49,000 Lake Tahoe residents that it’s redirecting 75% of their electricity supply to data centers — and they have less than a year to find a new power source. It’s one of the starkest examples yet of the AI boom’s impact on everyday Americans.
The case is extreme, but the pattern is not. Across the country, data center electricity demand is reshaping the grid, driving up rates, and pushing a growing number of homeowners toward solar and battery systems — not as complementary power, but as essential infrastructure.
NV Energy, the Nevada utility that has supplied the bulk of Lake Tahoe’s electricity for decades, told Liberty Utilities — the small California company that services the region — that it will stop providing power after May 2027. The reason: NV Energy needs the capacity for data centers being built by Google, Apple, and Microsoft around the Tahoe-Reno Industrial Center east of Reno, according to Fortune.
The numbers are staggering. Data centers consumed 22% of Nevada’s electricity in 2024, and that share could rise to 35% by 2030. Twelve data center projects in Northern Nevada alone could drive 5,900 megawatts of new demand by 2033, according to Desert Research Institute analysis of NV Energy’s resource plan. In NV Energy’s own 2024 filing, about 75% of major-project load growth is attributed to data centers.
This isn’t just a Nevada problem. AI data centers are expected to triple their share of US electricity consumption, from 4.4% in 2023 to 12% by 2028. Data centers drove half of all US electricity demand growth last year. In Virginia, they already consume more than one in four kilowatt-hours generated in the state.
The downstream impact on residential customers is direct. Dominion Energy in Virginia proposed its first base-rate increase since 1992 — adding about $8.51 per month in 2026 — driven in large part by infrastructure needed to serve data center load. The national average residential electricity rate hit 17.45 cents per kWh in January 2026, a 9.5% increase year-over-year, far outpacing regular inflation.
Google spent $4.75 billion last year chasing power for its AI data centers. That money is competing directly with residential customers for the same grid capacity.
The residential solar market took a hit when Congress eliminated the 30% federal tax credit for customer-owned systems at the end of 2025. Installations are expected to decline 18% in 2026, according to SEIA. But underneath that headline number, something interesting is happening: the motivation for going solar is shifting from incentives to infrastructure.
Rising rates and grid reliability concerns are replacing tax credits as the primary driver of residential solar adoption. Markets like Texas, Arizona, and parts of the Southeast — not traditional solar strongholds — are seeing increased interest in solar-plus-storage systems driven by reliability concerns and extreme weather, not just high electricity prices.
The shift is measurable. Third-party ownership models (leases and power purchase agreements), which still qualify for the commercial investment tax credit through 2027, are projected to grow 25% in 2026 and capture up to 69% of residential installations, up from roughly 45% in 2025. Homeowners aren’t waiting for incentives to come back — they’re finding new ways to get solar on their roofs.
Batteries are becoming the centerpiece of the home energy equation. As net metering policies evolve and time-of-use rates become more complex, a battery that can store cheap solar energy and deploy it during peak hours is increasingly essential. California utility customers alone are adding roughly 8,000 new home batteries per month — about 100 MW of new storage capacity.
Municipal programs are accelerating the trend. Ann Arbor, Michigan, recently became the first US city to directly deploy solar and battery systems on 150 homes through its city-owned utility. Vermont’s Green Mountain Power is offering home batteries at little to no upfront cost. These programs signal that utilities themselves recognize the value of distributed energy.
What makes the Lake Tahoe situation so instructive is the jurisdictional mess. Liberty Utilities is a California-regulated company, but its grid sits inside NV Energy’s balancing authority. California regulators can’t order Nevada to keep the lights on. Building a direct connection to California’s grid would cost hundreds of millions of dollars.
Liberty has asked California regulators to authorize an emergency procurement of replacement power before the May 2027 deadline. But as one Lake Tahoe resident and energy policy expert told Fortune: 49,000 customers competing in the Western electricity market against major utilities and data center operators have zero leverage.
That dynamic — small residential customers losing out to massive industrial electricity buyers — is exactly what’s driving the broader shift to distributed solar and storage. When the grid becomes unreliable or unaffordable because of data center demand, the homeowners who have solar panels and a battery in the garage are the ones with options.
We’ve been covering the surge in home solar and battery adoption for a while now, and the Lake Tahoe story crystallizes why this trend has legs beyond tax incentives.
The fundamental problem is that data centers need enormous amounts of electricity, and the infrastructure to deliver it is being built — or redirected — at the expense of residential customers.
Billionaires and their self dealing wealth generating companies are like a PacMan gobbling up all the resources and leaving scraps for the masses.

All 3 branches of US government have been hijacked.

This is unsustainable. At some point, something is going to break in a very bad way
For the most part, the story has been about the added demand putting pressure on residential prices, but when a utility tells 49,000 people that their power is being rerouted to serve Google and Apple, things are getting more serious and urgent. That’s a reason to put solar panels on your roof.
The residential solar industry is going through a painful transition after losing the federal tax credit. Installations might drop this year. But the underlying demand drivers — rising rates, grid strain from data centers and electrification, and the falling cost of solar and batteries — are all getting stronger, not weaker. Long-term retail rate inflation, falling equipment costs, and expanding grid services opportunities will continue to push adoption even without government incentives.
The market is shifting from one where homeowners asked “Should I install solar?” to one where they ask “How do I make solar and storage work for my home?” That’s a fundamental maturation, and stories like Lake Tahoe are only going to accelerate it.
As data centers put mounting pressure on the grid and electricity rates climb, solar and batteries are becoming essential home infrastructure — not a luxury. With lease and PPA options, you can go solar with zero upfront cost and start saving immediately. If you want to find the best deal, check out EnergySage. It’s a free service with hundreds of pre-vetted installers competing for your business, so you save 20 to 30% compared to going it alone. No sales calls until you pick an installer. Get your free quotes here.
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REDWOOD CITY, CA — Local leaders and clean energy advocates gathered late April at the San Mateo County Office of Education to celebrate the activation of a state-of-the-art solar photovoltaic system.
The 400-kilowatt installation, featuring both rooftop and carport panels, is projected to generate 13 million kilowatt-hours of clean power over the next two decades, yielding more than $1.5 million in savings for taxpayers, official said.
The system is a cornerstone of Peninsula Clean Energy’s GovPV program. On peak days, the new array is capable of producing more electricity than the SMCOE facility requires, effectively turning the building into a net-positive energy site.
“Sustainability is a core practice of the County Office of Education, and this new solar array is a shining example of our commitment,” said San Mateo County Superintendent of Schools Marco Chávez. He emphasized that the project aims to serve as a blueprint for school districts throughout the region to adopt similar green technologies.
The collaboration is part of a broader partnership that provides career and technical training for students in clean energy trades and supports a School Decarbonization Program to transition local schools to all-electric power.
“This project reflects what’s possible when local communities lead on climate solutions,” added Redwood City Mayor Elmer Martinez Saballos. Officials noted that the project was also among the first to benefit from federal Inflation Reduction Act incentives, allowing tax-exempt public entities to claim credits directly to lower energy costs.
Peninsula Clean Energy, the official electricity provider for San Mateo County and Los Banos, plans to complete 36 similar installations by June 2026. Other featured sites include the Menlo Park Library, Millbrae City Hall, and the San Bruno Aquatic Center, part of a region-wide effort to reach 100 percent renewable electricity by 2025.
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Jackie Gillis
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May 12, 2026, 10:14 PM
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Updated
A floating solar panel could soon be making its way to a Peekskill reservoir.
Camp Field Reservoir is the source of drinking water for thousands of people in the area.
According to a proposal, Camp Field Reservoir may be the home to a Floating Solar Array.
News 12 spoke with the Ecological Citizens Project, a Peekskill nonprofit that is working on this proposal.
"This proposed system would sell the electricity generated from the floating solar array and any Peekskill resident could subscribe to get energy from it," said Jason Angell, the co-director of the Ecological Citizens Project.
Angell says there are benefits to projects like this.
"It could help them lower their electricity bill and really have a 25-year fund to help fight food insecurity, but we're always open to hearing what people have to think," Angell says.
At a Tuesday night public hearing, one person spoke in favor of the project.
"The revenues going into funds that are helping this community grow its own food and hardening itself against the shocks, it seems absolutely necessary that we do this," said a Peekskill resident.
But, not everyone is on board.
"Putting it on top of our drinking water reservoirs is really irresponsible," said Peter Korcz, a Peekskill resident. "We have a lot of buildings over here that have roofs without solar panels that can very easily do that, and it will achieve the same exact results without potentially contaminating our water."
Supporters say there is a water treatment plant located on the reservoir site.
The developer says regular water quality testing will be done. If something harmful is found, the developer says it will remove the panels at no cost to the taxpayers.
No decision was made Tuesday night. The city says the project must undergo the environmental review.
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Published on May 13, 2026
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Bulli Creek solar-battery project is reshaping Australia’s renewable construction sector after developers redesigned the first phase to prioritize battery storage and reduce exposure to negative daytime electricity prices. The estimated $2.5 billion development in southern Queensland will now begin with a smaller 300MW solar facility paired with a 425MW/1,700MWh battery system. Developers expect the revised configuration to improve project viability while strengthening grid stability during evening demand peaks.
Genex Power revised the original development strategy after failing to secure sufficient equity support for a standalone utility-scale solar installation. The initial plan proposed a 775MW first-stage solar development before introducing storage later in the construction timeline.
However, worsening market conditions forced the company to rethink the project structure. Rooftop solar systems continue flooding Australia’s National Electricity Market (NEM) with cheap daytime electricity. Consequently, wholesale prices frequently fall into negative territory during peak solar production hours.
Genex chief executive Craig Francis said developers could no longer ignore the financial risks facing large standalone solar projects. Therefore, the company decided to bring forward battery construction so stored electricity can be dispatched during more profitable evening demand periods.
The Bulli Creek development still ranks among Australia’s largest planned renewable energy projects. Once fully completed, the facility could deliver up to 2GW of solar generation capacity alongside battery storage reaching 600MW and 2,400MWh.
The Bulli Creek solar-battery project redesign significantly changes the construction sequence and financing structure. Under the original schedule, developers expected to financially commit the first 775MW stage by the end of 2025 while beginning construction this year.
Developers also intended to introduce a 400MW/1,600MWh battery midway through the first solar construction phase. However, the revised plan now combines both assets from the beginning of the project rollout.
Genex currently targets a final investment decision, financial close, and construction start in 2028. Although the project already holds planning approvals, the redesign requires a fresh grid connection assessment process.
Francis explained that the revised approach lowers costs while improving investor confidence. He also noted that future development phases will likely follow a similar structure by pairing moderate-scale solar installations with large battery systems.
Across Australia, renewable energy developers increasingly prefer integrated solar-plus-storage projects instead of standalone solar farms. Large battery systems help operators store excess daytime electricity and release energy during evening demand peaks when prices rise.
Energy analysts believe the “solar duck” effect continues reshaping renewable construction planning nationwide. Rooftop photovoltaic systems now generate massive daytime electricity volumes, forcing utility-scale solar developers to rethink project economics.
The Bulli Creek solar-battery project continues supporting regional development commitments despite the revised construction timeline. Local stakeholders expressed concern after developers reduced the scale of the first phase and delayed the expected construction start.
Community members worried the slower rollout could affect employment opportunities, contractor participation, and infrastructure investment around Millmerran, the nearest town to the project site.
Francis acknowledged those frustrations while reaffirming the company’s long-term commitment to the region. Consequently, Genex decided to separate several community funding initiatives from the project’s final investment decision process.
One key initiative involves the redevelopment of the Domville Place community hub in Millmerran. Genex confirmed it will immediately release funding for the project so construction can begin next year instead of waiting for financial close on the renewable energy development.
Genex acquired the Bulli Creek project in 2022 after the development had already secured government planning approvals. Since then, the company has continued refining the project structure to align with changing market conditions across Australia’s renewable energy sector.
Developers now consider large-scale battery infrastructure essential for future renewable construction projects. Therefore, Bulli Creek’s revised strategy could influence how other utility-scale solar developments approach financing, project sequencing, and long-term grid integration.
The Bulli Creek solar-battery project redesign also reflects a broader transition across Australia’s renewable construction sector, where developers increasingly prioritize large-scale storage infrastructure to stabilize electricity supply and improve project economics. A similar trend recently emerged in Victoria after the Koorangie Energy Storage System reached full operational capacity with 185MW/370MWh of storage using Tesla Megapacks and grid-forming inverter technology. The Victorian project now provides critical system strength services while supporting renewable energy integration across the Murray River Renewable Energy Zone.

Project name: Bulli Creek Solar-Battery Project
Location: Southern Queensland, Australia
Estimated project cost: $2.5 billion
Project type: Utility-scale solar and battery energy storage development
Total planned solar capacity: 2GW
Total planned battery capacity: Up to 600MW / 2,400MWh
Revised first-stage solar capacity: 300MW
Revised first-stage battery capacity: 425MW / 1,700MWh
Original first-stage solar plan: 775MW
Original battery proposal: 400MW / 1,600MWh
Expected construction start: 2028
Current project status: Fully permitted with revised grid connection process underway
Main project objective: Improve commercial viability and reduce negative pricing exposure
Community investment initiative: Domville Place redevelopment funding
Nearest regional town: Millmerran
Project Developer and Owner: Genex Power
Strategic Investment Partner: J-Power
Chief Executive Oversight: Craig Francis, Genex Power CEO
Grid Connection and Market Authority: National Electricity Market (NEM) operators and Queensland grid authorities
Battery Storage Integration Scope: 425MW / 1,700MWh utility-scale battery energy storage system
Solar Construction Scope: 300MW first-stage solar farm development
Engineering and Technical Advisory Scope: Project redesign, grid optimization, and staged construction planning
Community Infrastructure Commitment: Domville Place community hub redevelopment in Millmerran
Planning and Environmental Approval Authorities: Queensland Government regulatory agencies
Future EPC Scope: Solar farm, battery installation, transmission infrastructure, and grid integration works
Project Type: Utility-scale solar and battery storage renewable energy development
Strategic Objective: Reduce negative wholesale pricing exposure and improve evening peak energy supply
Long-Term Development Target: 2GW solar generation capacity with up to 600MW / 2,400MWh battery storage capacity
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Yet another excellent article by Ivy Main – great job as always (including informing us on important energy-related stuff we might not have known about, debunking the vast amounts of misinformation about clean energy being spewed out there by fossil fuel interests, etc.)!
The conventional wisdom was wrong. And having helped spread the conventional wisdom, I was wrong, too. Mea culpa. It turns out sheep aren’t the only animals capable of handling the job of vegetation management on solar sites.
Farmers are finding that cattle also thrive among solar panels – and they will get their chance to prove it in Virginia.
What’s that, you say? You didn’t know there was a conventional wisdom on this topic, maybe because you really haven’t given much thought at all to solar grazing, so while you have nothing but respect for cattle, sheep and other ruminants, this strikes you as perhaps a bit, shall we say, niche?
Oh, but it’s not. Persuading cattle farmers that it’s in their interest to embrace solar is the key to unlocking low-cost energy supplies in Virginia and ending the rural war on solar.
Not that there’s anything wrong with sheep! In fact, sheep deliver such perfect synergy with solar that including them at solar farms is no longer novel.
The sheep thrive with the forage and shade, and in return they eat the vegetation that would otherwise grow up around the solar panels. Their grazing largely replaces labor-intensive (and polluting) mowers and herbicides while improving soil quality. Thanks to this symbiotic relationship, farmers have managed to keep their land and even grow their operations at farms across the U.S.
The advantages on all sides are so well understood within the solar industry that it’s common these days for new utility-scale projects in Virginia to include plans for grazing. Developers and utilities including Dominion Energy tout the local benefits of their partnerships with sheep farmers and beekeepers.
Yet there are more than 15 times as many cattle as sheep in Virginia, many of them in small herds on family farms.
The market for beef is vastly bigger than the market for lamb, so persuading farmers they should diversify into sheep as well as solar is a tall order.  But if cattle prove as compatible with solar as sheep are, there will be vastly more opportunities for both farmers and the solar industry. Given the dire economic situation facing small farms in Virginia today, “cattle-voltaics” could offer a lifeline for rural communities.
Solar site owners and farmers have proceeded cautiously with cattle, fearing the animals might damage expensive solar infrastructure – or themselves – given their great weight and propensity for rubbing their heads on things. And being much taller than sheep, they don’t fit as well under solar panels, which at some times of the day will tilt close to the ground to take maximum advantage of the sun’s rays. Making the supports taller and stronger adds cost. Hence the preference for sheep.
That’s all wrong, according to Josh Bennett, an executive with Colorado-based Huwa Enterprises who spoke at the Virginia Solar Summit in Richmond last month. Since 2023, Huwa has been helping farmers and ranchers integrate cattle with solar in Colorado and elsewhere, and Bennett is now intent on spreading the word that it works.
At a 2000-acre solar farm in Indiana, he said, Huwa “hardened” the site for the cattle but did not raise the panels or change their tilt. According to Bennett they had “zero problems” with the cattle, all yearlings of a docile breed that stand about four and a half feet tall. Contrary to expectations, the cattle have shown no interest in using the steel poles as scratching posts.
Elsewhere, Tennessee-based Silicon Ranch, which includes sheep grazing on 15,000 acres across its 15-state solar portfolio, recently launched a technology that it calls CattleTracker.
The software automatically tilts solar panels to horizontal when cattle are present, allowing the animals to graze underneath. When the cattle are moved to other parts of the site, the panels return to their optimum tilt. Silicon Ranch has been testing the approach at its 3.5-MW solar farm in Rutherford County, Tennessee since 2023, while delivering the power to a local electric cooperative.
Here in Virginia, Marcus and Jess Gray see great potential in solar cattle. The husband-and-wife owners of Gray’s Lambscaping are among the half dozen or so Virginia sheep graziers who contract with owners of large solar farms for vegetation management.
The American Solar Grazing Association featured the Grays, along with beekeeper Allison Wickham of Charlottesville-based Siller Pollinator Company, in a terrific video that was shown at the Solar Summit to great applause from the home team.
For the Grays, solar cattle are the obvious next step in integrating solar into Virginia’s farm culture.  At the Solar Summit, Marcus Gray described how he is raising Dexter cattle, a breed that is smaller and more docile than some others, with plans to graze them under solar panels. However, Gray did not provide a target date or site to graze what he calls his “inverter cattle.”
Virginia leaders recognize the importance of further developing agrivoltaics as a way to support both farming and energy production.
The General Assembly passed a bill this session defining agrivoltaics, and the administration of Gov. Abigail Spanberger plans to form a working group to promote it. In addition to grazing and beekeeping, agrivoltaics can include raising crops between rows of panels, a practice that is mostly still in the research stage in Virginia.
The administration’s working group should look for ways to encourage all of these practices, but if it only does one thing, it should create a demonstration program to help farmers understand how to integrate solar and cattle grazing into their operations. Virginia has a huge stake in making solar appealing to rural communities. We need to save our family farms, and we need the low-cost energy that solar provides.
The potential of agrivoltaics is huge, but until farmers see solar as a valuable opportunity for themselves and their families, Virginia will struggle to produce enough electricity to meet our growing demand.
This article was originally published in the Virginia Mercury on May 8, 2026.
The purpose of Blue Virginia is to cover Virginia politics from a progressive and Democratic perspective – and to help elect Democrats. This is a group blog, founded by me, Lowell Feld, but now including several other progressive writers.Read More
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India Adds Over 18 GW Solar Capacity In 2026 As Total Installed Solar Base Crosses 154 GW  SolarQuarter
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The company’s first direct clean energy initiative marks its continued commitment to sustainability and community impact.
RICHMOND, Va., May 13, 2026 /PRNewswire/ — Insight Global, an international talent and consulting company, announced today it has made investments in renewable energy with the installation of a rooftop solar energy system in Richmond, Virginia. The project has been operational since early spring of this year and is Insight Global’s first direct clean energy initiative in the company’s overall climate strategy.

The installation includes a 112.89-kilowatt solar array made up of 210 panels, expected to generate approximately 156,647 kilowatt-hours of renewable electricity annually. The energy will be used to help power Insight Global’s day-to-day operations at the Monument Consulting office, an Insight Global subsidiary located on Summit Avenue.
“We’re making this investment because it’s the right move for our business and the right move for the future,” said Jenny Sabo, Senior Vice President of Communications, Benefits, & ESG. “Our partnership with Cherry Street Energy allows us to step into renewable energy in a way that’s both operationally smart and financially sound.”
Insight Global operates primarily in leased office spaces, which traditionally can limit control over building infrastructure. Through a strong partnership with the building’s owner, who is also the founder of Monument Consulting, the company was able to move forward with this meaningful investment.
“As IG increased our attention on sustainability and solutions, I realized I had a unique opportunity to support the company through my ownership of Monument Consulting’s office building and the ability to evaluate solar energy generation from our rooftop,” said Matt Aprahamian, Founder of Monument Consulting. “We are implementing a solution that will have a significant impact on our organization and our communities.”
This solar energy system was financed and installed in partnership with Atlanta-based power provider Cherry Street Energy, who entered into a 20-year Power Purchase Agreement (PPA) with Insight Global.
“We welcome Insight Global into our distributed power network,” said Michael Chanin, founder and CEO of Cherry Street Energy. “Whether it’s schools, manufacturers, the World’s Busiest Airport, or one of the largest talent and consulting companies in the U.S., our platform helps customers control energy market variability with reliable, affordable electricity.”
As Insight Global continues to advance its own sustainability initiatives, the company also partners with customers to deliver talent and consulting solutions that support their environmental goals. Examples of this consulting work include:
About Insight Global:
Insight Global is an international talent and consulting company that delivers business outcomes in an ever-changing world. We obsess over solving problems and building solutions that move our customers further, faster.
 With access to top talent in more than 50 countries, our tech-enabled recruiters can build teams quickly. Our technical experts across Cloud, AI, Data, Enterprise Operations, and Applied Engineering deliver solutions tailored to each customer’s needs. As those needs evolve, so do we.
As we evolve, though, we stay true to our purpose: to develop our people personally, professionally, and financially so they can be the light to the world around them. It shows up in everything we do, from investing in our people to delivering results for our customers to making a meaningful impact in our communities.
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Union Minister for New and Renewable Energy Pralhad Joshi highlighted that renewable energy is becoming a critical determinant of competitiveness in key industrial sectors such as steel, aluminium, chemicals, automotive and textiles. He emphasised the importance of emerging areas including green hydrogen, battery storage, pumped hydro, offshore wind and round-the-clock renewable energy solutions in the next phase of growth.
Image: Yann Forget, Wikimedia Commons
India’s clean energy transition is no longer confined to climate commitments but is now central to shaping India’s industrial competitiveness, trade positioning, and long-term economic resilience, said Union Minister for New and Renewable Energy Pralhad Joshi recently.
Addressing the CII Annual Business Summit 2026, the Minister highlighted that India’s journey towards 500 GW of non-fossil fuel capacity is simultaneously laying the foundation for a globally competitive, innovation-driven and Aatmanirbhar [self-reliant] energy ecosystem.
The minister said that in the current global context, energy policy has become synonymous with industrial and trade policy. He pointed out that evolving global frameworks such as carbon-linked trade regulations are reshaping international markets.
Joshi noted that for the Indian industry, adoption of renewable energy is no longer optional but essential for maintaining export competitiveness and managing future cost pressures.
India has recorded one of the fastest expansions in renewable energy capacity globally. It has achieved significant growth across non-fossil energy, solar and wind capacity, as well as major advancements in domestic manufacturing of solar modules and cells.
The minister noted that renewable energy played a critical role in meeting India’s record peak power demand, contributing nearly one-third of the highest-ever demand of 256 GW. He further highlighted that at a time when global renewable energy investments declined by around 7%, India continued to attract strong investment flows, underscoring growing global confidence in its clean energy trajectory.
Key policy measures undertaken to strengthen the renewable energy sector include notification of long-term Renewable Consumption Obligation trajectories, introduction of Carbon Credit Certificate Regulations, 2026, long-term green ammonia procurement agreements, a standardised warranty framework for solar PV modules, the Renewable Energy Equipment Import Monitoring System, and tax and duty reforms supporting domestic manufacturing. Joshi stated that these measures aim to provide long-term policy stability, enhance investor confidence and promote domestic value addition.
The Minister highlighted that renewable energy is becoming a critical determinant of competitiveness in key industrial sectors such as steel, aluminium, chemicals, automotive and textiles. He emphasised the importance of emerging areas including green hydrogen, battery storage, pumped hydro, offshore wind and round-the-clock renewable energy solutions in the next phase of growth.
Shri Joshi expressed confidence that India is well on track to achieve its target of 500 GW of non-fossil fuel capacity by 2030. He stressed that the next phase will require deeper integration of generation, storage and transmission systems, along with enhanced grid resilience. He also underlined the importance of continued collaboration between government and industry to sustain the momentum of growth.
India’s non-fossil fuel capacity has increased from 81 GW in 2014 to 288 GW at present. Solar energy capacity has risen from 2.8 GW to 155 GW, while wind energy capacity has grown from 21 GW to 56.4 GW.
Acknowledging the role of industry stakeholders, Joshi stated that the progress achieved in India’s renewable energy sector is a result of strong public-private partnership. “The shared commitment between government and industry will be even more critical as we move towards building a globally competitive, technologically advanced and inclusive energy system,” he said. He invited industry stakeholders and global investors to participate in the upcoming Renewable Energy Global Investors Meet scheduled later this year.
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Plans for a massive solar farm in Will County once again got a no vote from the county’s Planning and Zoning Commission.
The commission’s 4-1 vote against Earthrise Energy’s plans for a 6,100 acre, 600-megawatt solar farm near Manhattan now goes to the Will County Board’s executive committee for review Thursday. The board is expected to vote on the project May 21.
Tuesday’s court-ordered hearing was Earthrise’s second round of hearings for its Pride of the Prairie project.
“I’m very pleased that they listened to the evidence and changed their vote to be more in opposition,” said Steven Becker, an attorney representing about 16 homeowners who live near the proposed solar farm.
Despite the commission’s continued stance against the project, Earthrise Energy officials remained optimistic. Last month, Will County Board members approved Earthrise Energy’s plans for a 2,400-acre solar farm near Crete.
“We appreciate the opportunity to respond to Mr. Becker’s questions regarding our Pride of the Prairie application and expect that the project will now be able to proceed to a vote of the County Board,” Rob Kalbouss, Earthrise Energy’s director of development​, said in a written statement after Tuesday’s hearing. “We are highly confident in the strength of our application and the many benefits that the project will deliver for Will County.”
Last month, Will County Judge Victoria Breslan ordered the Planning and Zoning Commission hold another hearing on the Pride of the Prairie proposal, finding Becker was not provided the opportunity to cross-examine Earthrise executives or present evidence on behalf of his clients during the previous public hearings. Her April 15 ruling came one day before the County Board was expected to vote on the project.
In their April vote, planning and zoning commissioners voted 4-2 against the project. Commissioner John Kiefner ​on Tuesday switched his previous yes vote to no. Commissioner Kimberly Mitchell, who previously voted no, was absent from Tuesday’s meeting.
Becker reiterated his argument ​Tuesday that Earthrise’s application was incomplete and should be denied.
He said it lacked information on the number of wetlands spread across the 96 parcels in Milton, Green Garden and Manhattan townships it intends to use. He also argued that Earthrise did not provide sufficient information on the 1 million solar panels it plans to install and that the 300,000 galvanized steel posts that would support the solar panels posed an environmental risk.
“Every one of these properties is unsuitable for this particular project,” Becker said of the 96 parcels included in Earthrise’s proposal.
During questioning, Becker also revealed that leases or contracts for the properties in question include a clause that Earthrise could use the properties for battery storage. When asked about project costs, Kalbouss would only say costs could be more or less than $1 billion. He declined to answer more specifically, saying that the company has not finalized project costs.
During a March 18 hearing before the Planning and Zoning Commission, Kalbouss said Earthrise was spending more than half a billion dollars for its 240-megawatt solar farm near Crete. Assuming the two projects have similar costs, Pride of the Prairie could cost $1.2 billion.
Kalbouss also noted that while the County Board is voting on a preliminary plan, the company must still comply with a final review of its plans by the county’s land use department before any building permits are secured. He added the company has no plans to include battery storage facilities, but if it ever did, those plans would have to be approved by the county.
Becker and Earthrise representatives will be in court again Thursday for a status hearing. Becker said he plans to challenge Earthrise’s presentation of a ​May 8 memo at Tuesday’s hearing, arguing that Earthrise was not allowed to present new evidence during that hearing.
Alicia Fabbre is a freelancer.
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VSB secures Sicily PV project approval  reNews – Renewable Energy News
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Solar Power Is So Big in Europe That Electricity Is Being Wasted  Bloomberg.com
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Heatwaves, rooftop solar and data centres force rethink of India’s power sector planning  Down To Earth
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PLANS for 416 solar panels at a new community-led energy scheme at a farm near Tisbury have been given the green light by Wiltshire Council.
Permission has been granted for the installation of 416 ground-mounted solar panels and an electrical enclosure at Pythouse Farm on Pythouse Lane in Tisbury.
The development, submitted by Nadder Community Energy Group, will see the panels installed on land to the north of the existing farm buildings, within a field currently used as a foraging area for free-range chickens on the Pythouse Estate. The new array will sit alongside an existing solar installation already operating at the site.
According to planning documents, the scheme will comprise a 262kWp solar photovoltaic system, arranged in 13 banks of panels across seven staggered rows. Electricity generated will be fed into the local grid via an underground cable connected to a small grey electrical enclosure located near the farm’s chicken sheds.
Proposed location of 416 new solar panels (Image: Singleton Design)
The site lies within the Cranborne Chase National Landscape (formerly Area of Outstanding Natural Beauty), meaning the proposal was subject to careful scrutiny over its potential landscape and visual effects.
However, planning officers concluded that the development would have limited and localised impacts. In their report, officers said the solar array would be well screened by existing woodland, hedgerows and farm buildings, and would not undermine the wider landscape character of the nationally protected area.
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Wiltshire Council’s landscape officer also supported the application, noting that while there are limited views from a nearby lane, additional hedgerow planting along the northern and western boundaries would help enhance local landscape character and improve biodiversity.
The planning permission includes a condition requiring boundary treatment details to be approved before the panels become operational.
The development will also be required to deliver at least a 10 per cent Biodiversity Net Gain, in line with national legislation, with enhancements such as bat and bird boxes to be provided.
Location plan (Image: Singleton Design)
Highways officers raised no objection after revised construction traffic arrangements were submitted, confirming that access could be safely managed during installation and that maintenance visits would be limited to around once a year.
West Tisbury Parish Council also voiced its support for the scheme.
Only one objection was received during consultation, with a resident suggesting solar panels should be installed on roofs rather than green fields. However, planning officers said national policy supports renewable energy developments where impacts can be made acceptable, and highlighted that the panels could be removed in the future with the land restored.
Granting permission, Wiltshire Council said the scheme would make a meaningful contribution to renewable energy generation and climate change goals, while allowing the land to continue in agricultural use.
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