Solar Now

ROOF SOLAR: Jared Salvatore, left, and Garrison Riegel, of Celestar Solar, carry a solar panel onto a roof in Schaumburg, Ill., on Nov. 30, 2023. Trent Sprague/Chicago Tribune/TNS

ROOF SOLAR: Jared Salvatore, left, and Garrison Riegel, of Celestar Solar, carry a solar panel onto a roof in Schaumburg, Ill., on Nov. 30, 2023. Trent Sprague/Chicago Tribune/TNS
The U.S. residential solar industry is cratering after President Donald Trump eliminated a key tax credit for homeowners to install solar panels last year – and it’s dragging down residential battery additions, according to a new BloombergNEF report.
The U.S. is expected to add 4.1 gigawatts of residential solar in 2026, down 15% from 2025, according to a BloombergNEF projection. That would mark the lowest level of new residential solar installations in five years.
“The market is not expected to recover to the record levels of 2023 anytime in the next decade,” the report states.
TAX BREAK
The main reason for the anticipated drop in home solar is the sunsetting of a 30% tax break for homeowners late last year under the One Big Beautiful Bill, explains BloombergNEF’s June 15 report. This has made solar systems more expensive for consumers. Meanwhile, tariffs and other factors have raised costs for solar equipment too.
DECLINING SECTOR
Solar companies are feeling the pressure. According to the new report and company filings, Sunrun Inc is expecting a 25% drop in U.S. residential solar additions in 2026 compared to 2025, while Enphase Energy Inc, SolarEdge, and SunPower Corp are expecting declines of 22%, 20% and 15%, respectively. Back in April, Freedom Forever filed for bankruptcy, citing the elimination of the federal tax credit.
While most of the country is experiencing this drop, two states are bucking the trend: California, a longtime solar leader, and Florida, which passed a new pro-solar law last year. BloombergNEF projects Florida’s residential solar additions will hit 710 megawatts in 2026, a 62% increase over last year. California’s installations are also forecast to grow 17% in 2026. Both states are also leading on solar permit applications.
BATTERY CRUNCH
The national solar crunch is having a knock-on effect on home batteries, which are highly dependent on solar installations. About 1.4 gigawatts of home storage is expected to go online this year, down 26% from 2025.
But even as total home battery installations are down, the combination of residential solar with batteries is on the rise. As of the first three months of 2026, some 40% of new residential solar systems have a battery attached, BloombergNEF found, up from an average of 35% last year.
“Battery storage is the future of home solar,” said Cosmo van Steenis, a BloombergNEF analyst and co-author of the new report. “Batteries can lay up stores of solar power in the daytime and release them at night.”

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Vikram Solar is advancing the first phase of its planned 12 GW solar cell manufacturing facility and expects to commission 9 GW of cell production capacity by the third quarter of fiscal year 2027 (3QFY27), ending December 2026.
The expansion comes as India’s Approved List of Models and Manufacturers (ALMM) List-II took effect on June 1, 2026. Under the new requirement, solar PV modules deployed in projects covered by the ALMM framework, including government-supported schemes, net-metering installations, and open-access renewable energy projects, must use solar cells sourced from manufacturers listed under ALMM List-II.
“While certain under-construction projects have received transitional relief, the broader policy direction remains unchanged. With domestic cell capacity still trailing module capacity, access to ALMM-compliant cells and backward integration will increasingly differentiate manufacturers. As ALMM List-III for wafers and ingots remains under consultation for its proposed June 2028 implementation, the policy framework is expected to increasingly favour scaled, integrated players, accelerating industry consolidation over the medium term,” says Equirus Securities in its recent research note.
According to the research note, Vikram Solar is simultaneously expanding its module manufacturing capacity from 9.5 GW to 15.5 GW, with the additional capacity expected to be commissioned by the first quarter of fiscal year 2027.
The report notes that domestic cell capacity continues to lag module manufacturing capacity, making access to ALMM-compliant cells an increasingly important competitive factor for solar manufacturers.
Module-cell integration is expected to play an important role in Vikram Solar’s next phase of development. The report notes that the company has secured interim domestic cell availability through a 2GW ALMM-compliant sourcing arrangement with Jupiter International, ensuring domestic cell availability ahead of its planned backward integration. However, Equirus Securities said this agreement is unlikely to materially alter Vikram Solar’s earnings, as DCR-linked pricing premiums are likely to remain with cell suppliers rather than flow through to module manufacturers.
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The widespread deployment of renewable energy capacity in Spain has driven a decoupling of energy prices from volatile global gas prices, resulting in a 19% reduction in consumer electricity bills.
This is a key takeaway from a report, published today by think tank Ember, which looks at the impact of Spanish renewable energy deployment on the country’s power prices. The report examines changes in power prices across Europe in response to the 2022 Russian invasion of Ukraine and the US-Israel war with Iran and the closure of the Strait of Hormuz, two significant macroeconomic disruptions that drove up power prices in several European countries.
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The increase in power prices was particularly striking in countries that are more heavily reliant on fossil fuels. For instance, the average power price in Italy, a country that Ember described as “more gas-dependent” than Spain, reached €143/MWh (US$165.9/MWh), while Spanish energy prices were less than one-third of that, at €42/MWh.
This means that, according to Ember, a typical Spanish household is paying 19% less than it would otherwise pay if the country’s gas prices were as strongly tied to the global gas supply as they were in 2021. This translates to a reduction of €10 per household per month in bills.
The decoupling of Spanish power prices from global gas prices is the driving force behind these lower bills. Ember attributes this decoupling to the deployment of renewable energy capacity, which has reduced the impact of gas on the energy mix more broadly; according to Ember, Spanish wind and solar generation increased by 37% between 2021 and 2025, which means that, in the first five months of 2026, gas influenced just 9% of hours in the national energy mix.
This compares to gas influencing 52% of hours in Spain as recently as 2021. The graph below, from Ember, shows the impact of global gas prices on Spanish energy prices during the two global conflicts, the Russian invasion of Ukraine and the war involving the US, Israel and Iran.
Again, compared to Italy, the difference is stark; Ember calculates that gas influenced 75% of hours in the Italian energy mix in the first five months of this year, over eight times the influence seen in Spain.
Crucially, Spain has responded to its own internal challenges with a doubling down on renewable energy investment. April 2025 saw the Iberian grid endure a significant blackout, but rather than fall back on fossil fuel-powered generation in response to this treat to the country’s grid security, Spain has sought to expand its renewable energy sector.
Last November, the government passed a degree to support grid resilience and the deployment of battery energy storage systems (BESS), and figures from Ember show that since the blackout, Spain has added an average of 1.3GW of new solar PV and wind capacity each month, just above the 1.2GW of monthly capacity additions the year before.
“Spain’s long-term, ambitious push on wind and solar is paying dividends, shielding consumers from volatile fossil fuel prices,” explained Ember senior energy analyst, Europe, Criss Rosslowe. “Reforms introduced following the April blackout have sustained the energy transition, strengthening the shielding of power prices.”
The BESS piece is particularly significant, as the Iberian grid could stand to benefit from considerable strengthening. Not only in response to the blackout in particular, but to minimise the widespread curtailment that affects the Spanish grid, which has struggled to effectively deploy the sheer volume of renewable energy capacity that has been brought online in recent years.
Figures from Spanish grid operator Red Eléctrica estimate that renewables curtailment leapt from 0.1TWh in 2021 to 4.6TWh in 2025, driving an increase in annual grid balancing costs from €1.3 billion to €3.8 billion over this period; strengthening the Spanish grid is therefore a priority for both energy security and cost-saving reasons.
Regarding batteries, Spain now aims to have 22.5GW of operational energy storage by 2030, and Ember expects operational BESS in Spain to quadruple between 2025 and 2026.

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Chinese perovskite solar module producer UtmoLight launched its new module series at SNEC 2026 in Shanghai, China, including two products aimed at addressing reliability challenges and application-specific limitations in commercial perovskite photovoltaics.
The company said the new product line reflects a shift beyond efficiency gains and larger module formats toward products tailored to specific deployment scenarios. The lineup includes the Chuangshi S2 high-strength module and the Chuangshi S1 ultra-light module.
The Chuangshi S2 is a 2.81 m² perovskite panel designed for harsh outdoor environments. UtmoLight rates the module at 500 W and said it uses 3.2 mm tempered glass in a double-glass configuration. The company said the module can withstand a front-side mechanical load of up to 5,400 Pa, making it suitable for projects exposed to high winds, heavy snow and hail.
UtmoLight said the product addresses one of the key barriers to large-scale perovskite deployment: mechanical durability. The company developed the module in response to feedback from earlier field projects, including concerns about wind-induced cracking, snow-load deformation and long-term reliability in extreme climates.
According to UtmoLight, the use of tempered glass required modifications to the manufacturing process because perovskite thin-film stacks are sensitive to high temperatures and mechanical processing. The S2 combines tempered-glass encapsulation with the company’s Jichuang+ process platform, which includes optimized functional layers and deposition processes intended to balance mechanical strength, power output and long-term stability.
At SNEC 2026, Germany’s TÜV Rheinland issued a certificate for the S2 panel, recognizing its high-strength design. According to the certification body, the module passed static load tests of 5,400 Pa on the front side and 2,400 Pa on the rear side, as well as a hail impact test using 45 mm hailstones traveling at 33.9 m/s.
The Chuangshi S1 targets lightweight PV applications. The 0.72 m² module uses a 1.1 mm + 1.1 mm ultra-thin double-glass structure. It is 2.6 mm thick and weighs 4 kg, which UtmoLight said is more than 62% lighter than conventional PV modules.
The company said the S1 is designed for distributed PV, building-integrated photovoltaics (BIPV), low-load rooftops and mobile energy applications. Its lower weight enables adhesive installation, reducing the need for rails, clamps and roof penetrations. UtmoLight said the design can improve installation efficiency and reduce risks to roof waterproofing while maintaining the weather resistance of glass encapsulation.
Both products are based on UtmoLight’s vertically integrated perovskite manufacturing platform, which covers materials development, large-area coating and encapsulation. The company has previously identified large-area manufacturing and long-term outdoor validation as key steps toward perovskite commercialization.
In November 2024, UtmoLight’s first gigawatt-scale production line in Wuxi, Jiangsu, hit full-process integration. The initial 2.8m² perovskite module off the line delivered 450 W with a full-area efficiency of 16.1%. As it shifts mature pilot-line processes to large-scale output, UtmoLight targets a mass-production efficiency of 20%.
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SolShare 2, due to be available in the UK from August, can support up to 30kW capacity, an increase from the flagship 20kW product.
June 16, 2026
Allume Energy has redesigned its shared solar PV technology that enables a single rooftop installation to connect to multiple properties.
The Melbourne, Australia-headquartered company aims to tackle ownership and technical barriers to solar adoption for shared dwellings like apartments and social housing.  
SolShare 2, due to be available in the UK from August, can support up to 30kW capacity, an increase from the flagship 20kW product. It can support up to 15 connections. The rooftop solar array is intended for installation on flat blocks, enabling residents from multiple flats to access the solar generation.
SolShare 1 has been available in the UK since 2021, and in June last year Allume received a £4 million strategic investment from E.ON UK. 
Alongside the increased capacity of SolShare 2, Allume has made battery energy storage system (BESS) integration with the system more straightforward. A communal BESS stored in or near flats with the rooftop array pairs with the SolShare 2 system via an Ethernet connection. 
Related:Carlyle-backed Revera takes FID on 800MWh BESS: ‘a vote of confidence in Scotland’
The system, which is PV and supplier-agnostic, also allows residents to discharge to the grid, with grid-charging to follow.
According to Cameron Knox, CEO and co-founder of Allume Energy, compliance and regulations in the UK had made it “all but impossible” to install integrated solar and BESS at flats, “but SolShare 2 changes that.”
This comes as the UK government is gathering evidence on how to enable shared battery storage to be rolled out across the UK. A federal government subsidy scheme in Australia demonstrates how the UK government might hope to intervene to establish a network of community batteries in the UK. 
The call for evidence will gather views on how to scale up deployment, remove regulatory and commercial barriers, ensure safety, and make sure the benefits reach those unable to install private domestic energy storage, like renters and people living in flats. 
It cites Allume’s 2023 BESS installation at its SolShare 1 array on a Cardiff flat block, which the company says has seen grid energy demand drop 60-70%.
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Molly Green
Section Editor, Informa
Molly joined the team in 2024 and has led coverage on the UK sites. Now shifting to a more global view, Molly is interested in how legislation shapes market dynamics, covering the intersection of policy design, investment patterns, and energy transition pathways. 
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TOYO Co., Ltd. (Nasdaq: TOYO) has announced a $357 million capital investment to construct a 1.5 GW N-type heterojunction (HJT) solar cell manufacturing facility in the Houston metropolitan area. 
The project co-locates cell production with its existing Texas module plant to secure Section 45X tax credits and establish a fully integrated, domestic content-compliant U.S. supply chain. The integration is designed to shorten production cycles from raw wafer processing to finished modules. 
Engineering, facility design, and procurement planning are already underway, with full project completion and initial pilot production expected within the next 20 months. Utilizing the existing Houston site infrastructure mitigates greenfield development risks, streamlines local permitting processes, and allows the company to leverage its existing regional management team and labor pool, said the company. 
This latest expansion represents TOYO’s official entry into domestic U.S. cell manufacturing, a move heavily incentivized by the structural design of the Inflation Reduction Act (IRA). Under current U.S. framework guidelines, domestic cell manufacturing qualifies for direct Advanced Manufacturing Production Credits under Section 45X of the IRA, which provide $0.04 per watt for domestically produced solar cells. At full 1.5 GW capacity, this single facility stands to capture up to $60 million in annual production tax credits. 
Beyond direct 45X benefits, co-locating cell and module lines allows TOYO to offer developers a fully “domestic content” compliant product. This enables project buyers to secure the 10% domestic content bonus tax credit under the Investment Tax Credit (ITC) and Production Tax Credit (PTC) frameworks, which serves as a critical competitive advantage as developers increasingly reject modules reliant on imported cells.  
“Expanding into domestic cell manufacturing is the natural next step in our commitment to creating an integrated onshore solar supply chain from polysilicon to panels,” said Takahiko Onozuka, Chairman and CEO of TOYO. “Co-locating 1.5 GW of HJT cell capacity at our Houston module site significantly optimizes our capital allocation and infrastructure spend.” 
The announcement marks the next phase of a multi-year pivot away from tariff-exposed regions. TOYO initially announced its entry into the U.S. downstream market in late 2024 with a 2 GW panel assembly factory in Texas. However, as trade barriers evolved, assembly alone proved insufficient to insulate the manufacturer from geopolitical headwinds. 
To guarantee compliance under Foreign Entity of Concern (FEOC) rules and AD/CVD trade regimes, the company has had to rework its upstream pipeline. Early this year, TOYO secured a strategic supply contract with an unnamed U.S. polysilicon manufacturer. By feeding U.S.-sourced polysilicon into its cell production, the company aims to create a dual-source supply chain capable of withstanding shifting U.S. customs enforcement. 
The company continues to defend its global footprint against trade friction. A coalition of domestic U.S. manufacturers has scrutinized the TOYO’s international operations, alleging tariff circumvention. TOYO strictly denies these Ethiopia duty evasion claims, countering that its 4 GW cell facility in Ethiopia operates transparently while confirming that shifting midstream cell operations to Houston serves as a hedge against trade litigation. 
While scaling its North American footprint, TOYO has maintained a presence as an upstream partner in other Western markets. In late 2025, the manufacturer struck a solar cell supply deal with French module producer Voltec Solar, proving its ability to service the European market with high-efficiency cells even as it anchors its primary capital expansion in the American Sunbelt. 
The Houston plant will focus on producing next-generation N-type heterojunction (HJT) cells. This HJT technology establishes a new benchmark for power density by combining industry-leading conversion efficiencies, frequently exceeding 25%, with very low annual degradation rates. Engineered for maximum yield, HJT cells feature improved bifaciality and temperature coefficients, supporting high power production even in extreme heat. 
In the U.S. market, where fixed infrastructure, land, labor, and installation costs are high, maximizing efficiency is critical. TOYO’s high-density HJT technology dilutes these fixed upfront balance-of-system expenses by generating more megawatt-hours per acre, directly improving project returns for developers. 
The $357 million investment represents a substantial capital commitment relative to TOYO’s current market capitalization of $579 million. In its Q1 2026 financial results, TOYO posted revenues of $142.8 million, a 177% year-over-year increase, and generated a record net income of $28.4 million, driven by the scale-up of its international cell lines. 
The company expects to fund the Houston construction through a mixture of internal cash flow, non-dilutive project financing, potential strategic partnerships, and selective equity financing. The new facility is expected to create approximately 400 direct full-time manufacturing jobs in the Houston metropolitan area, with an estimated 1200 additional jobs across the regional supply chain. 
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“I’m extremely happy with my decision.”
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As more homeowners look for ways to shield themselves from rising energy costs, one real-world home electrification setup is drawing attention for doing more than just keeping the lights on.
In a LinkedIn post, summarized by Electrek, microgrid expert and GM Energy employee Jim Reilly shared how his rooftop solar panels, home battery, and electric truck are helping him lock in his energy costs for decades.
Reilly outlined his all-electric setup: a rooftop solar array, a GM Energy home backup battery, and a GMC Sierra EV that can send power back to the house through bidirectional charging.
The hardware and materials for his solar-plus-vehicle-to-home system came to roughly $15,000 before discounts and tax credits. The panels are expected to produce about 10,000 kilowatt-hours annually, or around 253,000 kWh over the warranty period. Using that math, Reilly estimated the electricity cost works out to about $0.06 per kWh over the next quarter-century.
Reilly’s calculations highlighted how impactful clean energy upgrades can be for lowering household energy costs. By pairing solar panels with a home battery, he can also store excess energy generated during the day and use it later, helping him avoid expensive peak electricity rates.
If you’re curious about how much solar panels and battery storage can reduce your energy bills, connect with EnergySage. Its free tools can snag you competitive quotes from vetted installers. 
EnergySage has partnered with electrification company Qmerit to ensure homeowners can grab the best deals possible on battery storage based on their home and budget. 
On the EV side of the equation, Reilly contrasted a gas-powered Silverado with a 24-gallon tank with his Silverado EV equivalent. At $5.25 per gallon, the gas truck costs $126 for a fill-up, while charging the EV’s roughly 200-kWh battery at his solar rate costs about $12, a difference of $114 each time.
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Battery backups are often framed as storm-prep tools, but Reilly’s post points to another benefit: cost stability. Instead of being exposed to swings in gasoline prices or relying entirely on utility rates, homeowners with solar, storage, and EV charging can shift more of their energy use to power they generate themselves.
Those savings can add up quickly for frequent drivers. Reilly estimated that a full EV charge costs about $28 using grid electricity at home — far less than the $96 to $126 he typically spent filling a gas tank. When powered by his solar system, the cost of driving drops even further.
Reilly noted that his setup provides “backup power for those bad winter storms.” For homeowners dealing with outages and rising bills, the setup offers both reliability and lower fueling costs.
Reilly acknowledged that his exact math “might not work for everyone,” especially because he was able to install the solar himself. Still, his example shows how home electrification can pay off.
“I’m extremely happy with my decision,” Reilly added. 
If Reilly’s testimony has you considering a solar panel or battery upgrade, check out EnergySage’s free resources. It offers helpful mapping tools to understand the average costs of battery and solar upgrades in your area, as well as details on local incentives. 
If you’re not looking for a whole-home battery, Pila offers plug-and-play battery options that are a fraction of the cost of larger systems and require no installation. 
While Pila’s Mesh Home Battery is only roughly the size of a briefcase, it has enough power to keep your fridge running for 32 hours during an outage or charge your phone over 100 times.
Get TCD’s free newsletters for easy tips, smart advice, and a chance to earn $5,000 toward home upgrades. To see more stories like this one, change your Google preferences here.
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The global energy sector is experiencing a historic transformation as nations seek cleaner, more sustainable alternatives to fossil fuels. Rising concerns about climate change, carbon emissions, and energy security have placed renewable energy at the center of future development strategies. Among all renewable technologies, solar power has emerged as one of the fastest-growing and most accessible energy solutions available today.

Solar panels, once considered a niche technology, have become a mainstream source of electricity for homes, businesses, industries, and utility-scale power generation projects. Advances in photovoltaic technology, falling installation costs, and strong policy support have significantly expanded solar adoption across developed and emerging markets alike.

As governments and organizations intensify efforts to achieve carbon neutrality and sustainable energy goals, the solar panel industry is entering a period of substantial growth. According to Renub Research, the global Solar Panel Market is projected to grow from

US$ 187.21 billion in 2025 to US$ 384.65 billion by 2034, expanding at a compound annual growth rate (CAGR) of 8.33% between 2026 and 2034. This impressive forecast highlights the increasingly important role solar energy will play in the global transition toward clean electricity generation.

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Solar panels are devices designed to convert sunlight into electricity through photovoltaic cells. These cells, typically made from silicon-based materials, absorb sunlight and generate electrical current through the photovoltaic effect.

Solar panels can be installed on residential rooftops, commercial buildings, industrial facilities, solar farms, and open land areas where adequate sunlight is available. Multiple panels are often connected together to form solar arrays capable of generating significant amounts of electricity.

The energy produced can be used immediately, stored in batteries for future use, or supplied to electrical grids. This flexibility has made solar power one of the most attractive renewable energy solutions available.

As concerns regarding environmental sustainability continue growing, solar panels have become essential tools for reducing greenhouse gas emissions and promoting energy independence across the world.

One of the strongest factors fueling growth in the solar panel market is the increasing global demand for renewable energy.

Governments, corporations, and consumers are actively seeking alternatives to conventional energy sources such as coal, oil, and natural gas. Renewable energy technologies provide a pathway to reducing carbon emissions while enhancing long-term energy security.

According to data referenced in the market report, global renewable energy capacity expanded by approximately 15.1% during 2024, reaching nearly 4,448 gigawatts of installed capacity. This remarkable growth demonstrates the accelerating pace of the worldwide energy transition.

Solar energy plays a particularly important role because sunlight is abundant, widely available, and environmentally friendly. Unlike fossil fuels, solar power generation produces electricity without releasing greenhouse gases into the atmosphere.

As countries continue establishing ambitious renewable energy targets, demand for solar panels is expected to remain exceptionally strong throughout the forecast period.

Government support remains a critical driver of solar panel market growth.

Many countries offer tax incentives, subsidies, grants, low-interest financing programs, and net-metering schemes designed to encourage solar energy adoption. These initiatives help reduce installation costs and improve the financial attractiveness of solar investments.

Net-metering programs, in particular, allow consumers to sell excess electricity back to utility providers, creating additional economic benefits for solar system owners. Such policies have significantly accelerated adoption rates in residential, commercial, and industrial sectors.

Governments are also investing directly in large-scale solar infrastructure projects to support national renewable energy objectives and reduce dependence on imported fossil fuels.

As energy transition strategies continue evolving worldwide, policy support is expected to remain one of the most influential factors shaping market growth.

Continuous innovation in photovoltaic technology is making solar panels more efficient and cost-effective.

Over the past decade, manufacturers have achieved significant improvements in solar cell efficiency, allowing panels to generate more electricity from the same amount of sunlight. These advancements have helped increase system performance while reducing overall installation costs.

Modern solar technologies include bifacial panels, thin-film modules, enhanced energy storage integration, and high-efficiency photovoltaic cells. These innovations are improving energy output while expanding the range of applications for solar power systems.

Research and development efforts continue focusing on increasing durability, optimizing energy conversion rates, and lowering manufacturing expenses. As technology progresses further, solar energy is becoming increasingly competitive with traditional electricity generation methods.

The combination of improved performance and declining costs is accelerating solar adoption across global markets.

One of the most important developments within the solar industry has been the dramatic decline in system costs.

Historically, high installation expenses limited adoption primarily to large organizations and affluent consumers. However, advances in manufacturing efficiency, economies of scale, and technological improvements have significantly reduced prices.

Lower costs have made solar power accessible to a broader range of residential, commercial, and industrial users. Many consumers now view solar energy as a financially attractive long-term investment capable of reducing electricity expenses while increasing energy independence.

The continued decline in solar panel costs is expected to remain a major catalyst for market expansion, particularly in emerging economies where affordability plays a crucial role in technology adoption.

Among available solar technologies, monocrystalline panels continue to dominate due to their superior efficiency and performance characteristics.

These panels are manufactured using single-crystal silicon, which allows electrons to move more freely and efficiently through the material. As a result, monocrystalline panels generate more electricity per square meter than many alternative technologies.

Their high efficiency makes them particularly attractive for residential and commercial installations where available space may be limited. Additionally, monocrystalline panels are known for their durability and long operational lifespans.

Although they often carry higher upfront costs than some alternatives, their performance advantages continue driving widespread adoption across global markets.

Commercial organizations are increasingly investing in solar panel systems as part of broader sustainability and cost-reduction strategies.

Office buildings, shopping centers, warehouses, manufacturing facilities, and distribution hubs are utilizing solar installations to reduce electricity expenses and strengthen environmental credentials. Solar energy helps businesses improve operational efficiency while protecting against future energy price volatility.

Many organizations also view renewable energy investments as important components of corporate sustainability initiatives. Solar installations demonstrate commitment to environmental responsibility while supporting long-term business objectives.

Government incentives and declining installation costs have further strengthened the business case for commercial solar adoption. As organizations continue prioritizing sustainability, commercial demand is expected to remain a major growth segment within the market.

Electricity generation represents the most significant application area for solar panels worldwide.

Utility-scale solar farms are increasingly contributing to national energy supplies by providing clean, renewable electricity to millions of consumers. Governments and energy providers are investing heavily in solar infrastructure to diversify energy sources and reduce reliance on fossil fuel-based generation.

Large-scale solar projects offer numerous advantages, including lower operating costs, reduced environmental impact, and long-term energy security. Advances in energy storage technologies are also improving reliability by enabling solar power generated during daylight hours to be used when sunlight is unavailable.

As global electricity demand continues rising, solar power is expected to play an increasingly important role in meeting future energy requirements.

Off-grid solar systems are creating new opportunities for communities located far from traditional electricity infrastructure.

These systems operate independently of centralized power grids and often incorporate battery storage technologies to provide reliable electricity access. Off-grid solar installations are widely used in rural communities, agricultural operations, telecommunications infrastructure, and remote businesses.

Governments and development organizations increasingly support off-grid solar initiatives because they provide affordable and sustainable energy solutions for underserved populations.

The growing need to expand electricity access in developing regions is expected to contribute significantly to long-term market growth.

United States
The United States remains one of the largest solar markets globally. Strong policy support, increasing consumer awareness, declining costs, and substantial investments in renewable energy infrastructure continue driving adoption across residential, commercial, and utility-scale sectors.

United Kingdom
The United Kingdom is experiencing steady growth in solar adoption as the country pursues ambitious carbon reduction targets. Residential installations, commercial projects, and community solar programs continue supporting market expansion.

India
India represents one of the fastest-growing solar markets in the world. Abundant sunlight resources, government-backed renewable energy programs, and expanding infrastructure investments are driving rapid deployment across residential, commercial, industrial, and rural electrification applications.

Saudi Arabia
Saudi Arabia is accelerating investments in solar energy as part of broader economic diversification and sustainability initiatives. Large-scale solar projects are helping the country reduce dependence on traditional energy sources while supporting long-term renewable energy goals.

Challenges Facing the Industry
Despite strong growth prospects, the solar panel market continues facing several challenges.

High upfront installation costs remain a concern for some consumers, particularly in regions with limited financial incentives or financing options. Although long-term savings can offset initial investments, affordability continues influencing purchasing decisions.

Solar power generation also depends on weather conditions and sunlight availability. Variations in sunlight intensity, seasonal changes, and nighttime periods require supplemental energy storage solutions or grid integration.

Battery storage technologies continue improving, but additional costs associated with storage systems remain important considerations for many users.

Addressing these challenges will be essential for sustaining long-term market growth and maximizing renewable energy adoption worldwide.

According to Renub Research, the global Solar Panel Market is expected to grow from US$ 187.21 billion in 2025 to US$ 384.65 billion by 2034, representing a CAGR of 8.33% between 2026 and 2034. Growth will be supported by increasing renewable energy demand, favorable government policies, declining technology costs, and ongoing advancements in photovoltaic efficiency.

The market's strong outlook reflects the growing importance of solar energy in achieving global sustainability and energy transition objectives.

The solar panel industry stands at the forefront of the global clean energy revolution. As nations work to reduce carbon emissions, strengthen energy security, and achieve sustainability goals, solar technology is becoming an increasingly essential component of modern energy systems.

With Renub Research forecasting growth from US$ 187.21 billion in 2025 to US$ 384.65 billion by 2034, the market is poised for substantial expansion. Continued innovation in photovoltaic technology, energy storage systems, and manufacturing efficiency will further accelerate adoption across residential, commercial, industrial, and utility-scale sectors.

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Floating solar photovoltaic panels and battery storage system may be in the Manteca wastewater treatment plant’s future.
Staff is recommending the City Council authorize a no-cost technical feasibility study be conducted by Willdan Energy Solutions.
Once completed, staff will report back to the Council with a recommendation to either advance, delay, or not pursue the project.
Wildan is proposing a 1.7 mega-watt floating solar photovoltaic and battery system with an estimated $3.2 million in rebates.
The cost of the project would be funded from future cost savings from electricity generated.
What such solar projects typically do is stabilize electricity costs up to the load of electricity they generate.
As such it would help the city avoid future PG&E power rate increases for a large chunk of their power needs at the treatment plant.
The last time the city explored solar at the treatment plant in 2018, the annual PG&E bill for the facility was in excess of $1.4 million. There has been close to almost a dozen rate increases since then as well as additional demand for electricity created by housing growth.
Electricity is the biggest single operating cost for sewer treatment plant.
The city was approached by Wildan as well as Energy Systems Group earlier this year.
Energy System’s proposal involved a 1.8 mega-watt ground mounted solar photovoltaic system with an estimated $1.89 million in rebates.
That system would generate more electricity but would not include battery storage.
An advantage the Wildan proposal brings to the table is not using land for the placement of solar panels.
That would allow the city to have more flexible use for land connected with the treatment plant.
Eventually, the city wants to relocate its public works division and corporation yard into one location at the treatment plant.
The city has also toyed with the idea of other uses for some of the treatment plant land including as a possible organic waste processing site.
To contact Dennis Wyatt, email dwyatt@mantecabulletin.com

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MPC Energy Solutions NV ( (DE:5IX) ) has shared an update.

MPC Energy Solutions NV has secured the final permit for its 66.1 MWp San Patricio solar plant in Guatemala, allowing the project to begin testing and commissioning, with this phase expected to last around two weeks. The company now anticipates receiving the Commercial Operation Date certificate in July and has shifted its expected start of operations from the second to the third quarter of 2026.
During the testing period and until official commercial operations, MPC Energy Solutions will sell generated electricity on the spot market, while reaching COD will be a key milestone enabling the planned sale of the asset to proceed. To cover additional debt service, staffing and operating costs arising from the delay, the company has injected an extra USD 1.5 million, which it expects to recover almost entirely through price adjustments at the closing of the agreed sale, keeping project economics broadly in line with previous guidance.
More about MPC Energy Solutions NV
MPC Energy Solutions NV is a renewable energy developer that builds, owns and operates utility-scale solar photovoltaic projects, currently focusing on Central America. The company targets large-scale solar PV plants that can feed electricity into regional power markets, positioning itself as a player in the transition to cleaner energy in emerging markets.
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Nuvama Wealth Management, an India-based wealth management firm, has projected India’s solar demand growth through FY35. India’s solar demand is projected to grow at 22% CAGR over FY26-35E, while overall power demand will rise at 6%. Total power consumption is expected to increase from approximately 1,848 BU to nearly 3,228 BU by FY35. This increase represents more than 1,380 BU of incremental demand over the next decade for India. The report links solar-driven FDRE/RTC demand over FY26-35E to renewable power-intensive data centres and GH2. Solar’s consumption share is projected to rise from 9% in FY26 to 33% by FY35. The report estimates approximately 416 GW of incremental base solar capacity addition during FY26-35E for India. Green hydrogen and data centres are expected to require 251 GW in base case and 406 GW in bull case.

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The appointed developer will handle design, engineering, supply, financing, installation, testing and commissioning of the solar photovoltaic system and any Battery Energy Storage System (BESS) in line with the Ministry of New and Renewable Energy (MNRE), Central Electricity Authority (CEA), Maharashtra Electricity Regulatory Commission (MERC) and the respective distribution company (DISCOM) rules and the Maharashtra Renewable Energy Policy 2025–36. The contract includes 25 years of operation and maintenance and the supply of ALMM-compliant modules, inverters, balance-of-system equipment, metering and SCADA. Prior intimation through MAHAVITARAN or the respective DISCOM portal is mandatory before installation.
The tender is split into four categories, each allocated 25 MW to make up the 100 MW portfolio. Category A1-S covers 20–100 kilowatt (kW) solar-only installations while A1-B covers 20–100 kW projects with 30 per cent BESS for two hours. Category A2-S covers 101–250 kW solar-only projects and A2-B covers 101–250 kW projects with 50 per cent BESS for two hours. All components must meet safety and regulatory certifications and developers must secure electrical clearances during the online application.
The BESS must be fully integrated with the solar PV system to supply Behind-the-Meter load and be designed to deliver rated power for a minimum of two hours of continuous discharge. Developers must guarantee capacity retention of 80 per cent at Year 10 and 70 per cent at Year 15 from the Commercial Operation Date (CoD); any cell or module replacements must be covered by the RESCO within the quoted fixed tariff. Comprehensive BESS operation and maintenance must be provided for 25 years and projects must achieve a minimum Capacity Utilisation Factor (CUF) of 19 per cent per annum.
The Mahatma Phule Renewable Energy & Infrastructure Technology Limited (MAHAPREIT) has issued a tender for the development of 100 Megawatt (MW) of rooftop solar projects across Maharashtra under the renewable energy service company (RESCO) model. The procurement covers Behind-the-Meter (BTM) systems with and without Battery Energy Storage System (BESS) and the tender document is priced at Rs 10,000 plus 18 per cent GST. Bids close on June 23, 2026. The appointed developer will handle design, engineering, supply, financing, installation, testing and commissioning of the solar photovoltaic system and any Battery Energy Storage System (BESS) in line with the Ministry of New and Renewable Energy (MNRE), Central Electricity Authority (CEA), Maharashtra Electricity Regulatory Commission (MERC) and the respective distribution company (DISCOM) rules and the Maharashtra Renewable Energy Policy 2025–36. The contract includes 25 years of operation and maintenance and the supply of ALMM-compliant modules, inverters, balance-of-system equipment, metering and SCADA. Prior intimation through MAHAVITARAN or the respective DISCOM portal is mandatory before installation. The tender is split into four categories, each allocated 25 MW to make up the 100 MW portfolio. Category A1-S covers 20–100 kilowatt (kW) solar-only installations while A1-B covers 20–100 kW projects with 30 per cent BESS for two hours. Category A2-S covers 101–250 kW solar-only projects and A2-B covers 101–250 kW projects with 50 per cent BESS for two hours. All components must meet safety and regulatory certifications and developers must secure electrical clearances during the online application. The BESS must be fully integrated with the solar PV system to supply Behind-the-Meter load and be designed to deliver rated power for a minimum of two hours of continuous discharge. Developers must guarantee capacity retention of 80 per cent at Year 10 and 70 per cent at Year 15 from the Commercial Operation Date (CoD); any cell or module replacements must be covered by the RESCO within the quoted fixed tariff. Comprehensive BESS operation and maintenance must be provided for 25 years and projects must achieve a minimum Capacity Utilisation Factor (CUF) of 19 per cent per annum.
Smartworks has leased over 400 seats at its Mumbai centre to a subsidiary of a Japanese non-bank finance company in a Rs 350 million (mn) transaction. The company said the agreement covers managed office space designed to support the tenant’s India operations and will strengthen its presence in the city. The deal was presented as part of Smartworks’ strategy to grow its enterprise client base. The leased seating forms part of a larger workplace solution that combines private offices and flexible seating tailored to financial services clients. Smartworks noted that demand from the banking, fina..
Aequs Infra’s Belagavi special economic zone has moved close to complete renewable energy adoption for on-site industrial operations. Energy requirements within the cluster are met through a combination of rooftop solar installations, open access renewable energy procured from third-party providers and green power supplied by the state electricity board. The integrated approach has enabled the campus to sustain operational reliability while advancing environmental objectives. The licensed power distribution network within the campus supports stable energy delivery and creates economic benefits..
Waaree Renewable Technologies (Waaree) has signed a Letter of Award with its wholly owned subsidiary, Sunsational Power Private (SPPL), to develop a 300 megawatt (MW) and 450 megawatt peak (MWp) ground-mounted solar project. The company will provide engineering, procurement and construction services and two-year operation and maintenance services under the contract. The agreement covers the full EPC scope and a two-year O&M commitment. The scope will include site engineering, procurement of equipment and construction management across the installation. The project is scheduled to be completed ..
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More than 3,250 solar panels have been installed at the home of Welsh rugby, in what the stadium owner claims is the largest PV installation for a UK sports venue to date.
Venue owner Welsh Rugby Union (WRU) revealed it has been generating electricity at Cardiff’s Principality Stadium since February 2026, but better weather conditions in May and June has meant the array is now providing significant power for stadium operations.
Roof work for the project was completed over a six-week period, installer EvoEnergy told pv magazine. This was timed to run from mid-August to the end of September 2025 to ensure the system was installed in the off-season for the stadium.
The 1.5 MW array comprises 3,296 Trina 455 W modules with panel optimizers, mounted on K2 standing seam clamps. EvoEnergy said it used this mounting design to ensure a robust system given the building height and wind speed at the location, which is next to a river.
WRU expects the array to generate enough electricity each year to power more than 50 matchdays. The rugby association has also forecast the rooftop installation will provide return on investment within two-to-three years.
Completed in 1999, the 74,000 seater Principality Stadium – formerly the Millennium Stadium – was one of the first in the world to have a fully movable, retractable roof over a column free stadium. The solar installation made use of cranes located inside the stadium to hoist panels and equipment over the primary trusses on the roof, according to WRU.
Darren Crossman, head of facilities and safety and sustainability WRU, said that as custodians of an iconic stadium, “we have a responsibility to lead by example. This solar installation is a significant technical and operational step forward.”
Ascot Racecourse
One of England’s historic racecourses is also sporting a new solar array, following the installation of PV on the grandstand at Ascot.
The Ascot Racecourse rooftop solar array is installed across the 480-meter-long roof of the grandstand, and is expected to be energized later in 2026. Installer SSE Energy Solutions said the project comprises more than 1,200 solar panels with a total capacity of 608 kW.
Sam Thompson, director of estate operations at Ascot Racecourse, said the installation would allow the venue to take a major step forward in its plans to cut emissions and strengthen operational resilience.
“By turning our grandstand roof into a long-term energy asset, and bringing the system online later this year, we will be supporting both our environmental commitments and the future sustainability of the racecourse,” Thompson said.
Tamsin Lishman, customer asset director, SSE Energy Solutions, said that projects like Ascot show how commercial solar can be delivered at scale, even in complex and high profile environments.
The Principality Stadium and Ascot Racecourse installations are the latest in a line of PV projects deployed to some of the most famous sports venues in the United Kingdom. Manchester City’s campus and London Stadium both have their own solar arrays, as does The Wing grandstand at Silverstone – home of the British Grand Prix.

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Chart of the Day: Solar’s dominance over India’s renewable energy is getting starker  Moneycontrol.com
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The multinationals RWE and Meta formalized a new long-term power purchase agreement under a deal that formally links the electricity supply to be generated by the Rabbits Foot Solar project, a 298-megawatt alternating current facility located in Bowie County, North Texas. Civil works for the photovoltaic complex began during the first months of the current year, with the formal start of commercial operations estimated for late 2027.
Through this contractual addition, the operational alliance between both organizations is experiencing a substantial increase in its consolidated supply volume. Prior to this signing, the shared portfolio included the Emily photovoltaic assets in Illinois, Lafitte in Louisiana, and Waterloo in Texas, totaling a previous cumulative 574 megawatts. The incorporation of the new Texas plant brings the total jointly managed volume to 872 megawatts formally assigned over the last two fiscal years.
Regarding the socioeconomic development of the region, the construction phase of the project will require the hiring of approximately 200 local workers dedicated to the energy infrastructure sector. RWE executives indicated that the development of the complex will generate tax revenues exceeding $50 million projected over a 40-year term. These financial resources will be allocated directly to the budgets of Bowie County, the DeKalb Independent School District, Texarkana College, and Emergency District No. 6.
Likewise, institutional projections estimate that tax revenues will significantly strengthen medical assistance services, vocational technical training institutions, and road maintenance in the area. The operating company seeks to ensure that the technical deployment generates sustained financial stability in rural North Texas communities through direct investment in essential community assets.
On Meta’s part, the acquisition of this energy block responds directly to the corporate goal of powering its entire global data infrastructure with clean energy. The technology firm’s renewable energy management highlighted that the integration of Rabbit’s Foot optimizes the electricity supply of the Texas grid. This procurement scheme ensures clean and stable resources to absorb the growing demand originating from massive data processing.
At the same time, the North American subsidiary RWE Americas is consolidating its position in the U.S. generation market, where it currently operates 13 gigawatts distributed across 27 states. The energy corporation’s strategic plans include the addition of 9 gigawatts of net capacity by 2031. The fulfillment of this master plan seeks to support the requirements of industrial manufacturing, advanced computing centers, and general national economic electrification schemes.
Source and photo: RWE Americas
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Axial return to Intersolar Europe 2026, taking place from June 23 to 25 in Munich, Germany, where it will showcase its latest solutions for utility-scale photovoltaic plants  at booth A6.250.
The company’s presence at Europe’s leading solar exhibition coincides with a major milestone: according to Wood Mackenzie’s and S&P Global Global Solar Tracker Market Share 2026 reports, Axial achieved the largest share of the European solar tracker market by shipments in 2025, during a year in which the regional market reached a record 25 GWdc of shipments.
The company also secured the number one position in Italy, ranked second in Romania, and maintained its place among the world’s top 10 solar tracker suppliers.
Backed by  18 years of experience and 1,022 projects worldwide, the company arrives at the event, strengthening its presence in some of the world’s leading photovoltaic markets.
During Intersolar Europe, Axial will also highlight Titan, its solution for large-scale photovoltaic projects. The company describes this product as a new approach to optimizing utility-scale solar plants, designed to reduce project complexity and improve economics as plant size increases.
Titan is not simply a larger tracker. Its main features include tracker lengths of up to 160 meters, a reduced number of motors, the ability to accommodate up to four strings per tracker, and a lower number of foundations.
According to the company, Titan’s design also helps optimize electrical infrastructure, simplify installation and improve overall project economics.
“When scale increases, every component matters,” Axial states. Based on this principle, Titan aims to maximize photovoltaic plant efficiency through more efficient resource utilization and reduced operational complexity.
Alongside Titan visitors to the Axial booth will be able to explore the company’s complete tracker portfolio. Particular attention will be given to the  Axial Titan and theAxial 2TT, showcasing both the company’s latest innovation and one of the industry’s most proven tracker solutions.
The latter has helped establish Axial’s leadership position in Europe. Designed for utility-scale projects, the Axial 2TT combines a highly rigid structure with an innovative Multipoint Blocking System to deliver exceptional stability under demanding site conditions. Its simplified design, reduced component count and compatibility with large-format modules simplify construction and support reliable, long-term operation across the entire lifecycle of the plant.
At Axial, efficiency goes beyond energy production. It is the result of engineering solutions that simplify project execution, adapt to real world conditions and improve performance at every stage of development. By reducing complexity, accelerating installation, optimizing resource utilization and enhancing operational reliability, it helps its partners maximize the overall value of their solar projects.
With Titan, Axial takes the next step in its evolution from a leading European tracker supplier to a company focused on redefining efficiency at utility scale. By combining intelligent engineering, proven reliability and a deep understanding of project realities, Axial continues to develop solutions that help the solar industry deploy more complex plants with greater confidence and performance. At Intersolar Europe 2026, the company will showcase not only new technology, but also its vision for the future of utility-scale solar.
 
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Navitas Solar to Invest ₹1,500 Crore in Gujarat to Set Up 3.6 GW Solar Cell Plant Photograph: (Navitas Solar)
Solar module manufacturer Navitas Solar plans to invest around ₹1,500 crore in Gujarat to establish a 3.6 GW solar cell manufacturing facility and a pilot wafer-and-ingot production line, as the company moves deeper into upstream solar manufacturing amid India’s push for greater domestic value addition.
The proposed expansion, to be implemented in phases, marks Navitas Solar’s entry into solar cell manufacturing and a strategic move towards backward integration across the solar value chain. The first phase of the project is targeted for commissioning in 2027, subject to market conditions and project readiness.
The investment comes at a time when demand for domestically manufactured solar cells is expected to rise following the implementation of the Approved List of Models and Manufacturers (ALMM) List-II framework, which mandates the use of approved domestic solar cells in eligible projects.
Navitas Solar said civil work for the project, covering more than 10 lakh sq ft, is already underway. The company has finalised technology partnerships for the proposed manufacturing line and appointed senior leadership to oversee the new business vertical.
The planned cell manufacturing facility is being designed as a highly automated production unit with the flexibility to accommodate future technology upgrades, including next-generation solar cell architectures.
In addition to cell manufacturing, the company plans to set up a pilot wafer-and-ingot line in 2027 as part of its long-term strategy to strengthen upstream integration. The move is aimed at building in-house capabilities and reducing dependence on imported components, which continue to dominate key segments of the solar manufacturing supply chain.
“India’s clean energy transition requires strong domestic manufacturing capabilities across the solar value chain. This expansion is aimed at building a future-ready platform across modules, cells and deeper backward integration,” said Vineet Mittal, Director – Finance & Strategy, Navitas Solar.
The investment reflects a broader trend across India’s solar manufacturing sector, where companies are increasingly expanding beyond module assembly into cells, wafers and other upstream components to align with government localisation policies and reduce supply-chain risks.
Navitas Solar currently operates 3 GW of annual solar module manufacturing capacity and manufactures Mono PERC and TOPCon modules ranging from 40 W to 720 W. Through its subsidiary, Navitas Alpha Renewables, the company also manufactures solar encapsulants, giving it a degree of upstream integration.
The company said the proposed expansion could create nearly 1,000 direct jobs across manufacturing, engineering, operations and research functions, while generating additional employment in logistics and ancillary industries.
The planned cell facility is expected to position Navitas Solar among a growing group of Indian manufacturers investing in domestic solar cell production as the industry prepares for tighter localisation requirements and rising demand from utility-scale and commercial renewable energy projects.
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Gujarat Inject (Kerala) Wins ₹14.49 Crore Solar PV Module Order from Deon Energy, Strengthens Renewable Energy Transition  SolarQuarter
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Gujarat Inject Kerala Limited Bags Rs. 14.49 Crore Solar PV Module Order from Deon Energy Limited  Business Standard
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Industry sources indicate most manufacturers have struggled to maintain capacity utilisation above 70 per cent, which has contributed to upward pressure on prices. The company proposal arrives amid forecasts that fresh capacities of over six gigawatt (GW) may be added by September, which are expected to ease tightness by December 2026. The report notes that capacity additions could improve plant utilisation and market balance towards the end of the year.
The G12R wafer format, also known as 210R, is being regarded as the next evolution following the widely adopted M10 format and is said to offer higher module efficiency, lower production costs and improved line utilisation. Manufacturers consider the format helpful in narrowing the gap between nameplate capacity and actual output, thereby enhancing overall plant performance. This technical shift is influencing investment and manufacturing strategies across the sector.
The ALMM framework has been introduced to promote quality, reliability and traceability in the Indian solar sector while encouraging domestic manufacturing capacity. Grew Solar’s application is presented as part of broader efforts to build a self?sufficient renewable energy ecosystem and to secure market share for locally produced modules and cells. Observers expect that certification under ALMM List?II may support procurement by projects that require approved models.
Solar cells remain the core building blocks of photovoltaic modules and are central to determining system efficiency and long?term sustainability. The company application and ongoing format transition underline how manufacturing upgrades and regulatory alignment are shaping the domestic solar manufacturing landscape.
Grew Solar has applied for inclusion of its three point five gigawatt (GW) TopCon G12R solar cell manufacturing capacity at its Narmadapuram facility in Madhya Pradesh under the Ministry of New and Renewable Energy Approved List of Models and Manufacturers List-II for N?Type TopCon solar photovoltaic cells. The application comes as ALMM List-II came into force on the first of June and domestic TopCon cells and modules are reported to be in short supply. The move aims to secure regulatory recognition and support for locally made cells. Industry sources indicate most manufacturers have struggled to maintain capacity utilisation above 70 per cent, which has contributed to upward pressure on prices. The company proposal arrives amid forecasts that fresh capacities of over six gigawatt (GW) may be added by September, which are expected to ease tightness by December 2026. The report notes that capacity additions could improve plant utilisation and market balance towards the end of the year. The G12R wafer format, also known as 210R, is being regarded as the next evolution following the widely adopted M10 format and is said to offer higher module efficiency, lower production costs and improved line utilisation. Manufacturers consider the format helpful in narrowing the gap between nameplate capacity and actual output, thereby enhancing overall plant performance. This technical shift is influencing investment and manufacturing strategies across the sector. The ALMM framework has been introduced to promote quality, reliability and traceability in the Indian solar sector while encouraging domestic manufacturing capacity. Grew Solar’s application is presented as part of broader efforts to build a self?sufficient renewable energy ecosystem and to secure market share for locally produced modules and cells. Observers expect that certification under ALMM List?II may support procurement by projects that require approved models. Solar cells remain the core building blocks of photovoltaic modules and are central to determining system efficiency and long?term sustainability. The company application and ongoing format transition underline how manufacturing upgrades and regulatory alignment are shaping the domestic solar manufacturing landscape.
Smartworks has leased over 400 seats at its Mumbai centre to a subsidiary of a Japanese non-bank finance company in a Rs 350 million (mn) transaction. The company said the agreement covers managed office space designed to support the tenant’s India operations and will strengthen its presence in the city. The deal was presented as part of Smartworks’ strategy to grow its enterprise client base. The leased seating forms part of a larger workplace solution that combines private offices and flexible seating tailored to financial services clients. Smartworks noted that demand from the banking, fina..
Aequs Infra’s Belagavi special economic zone has moved close to complete renewable energy adoption for on-site industrial operations. Energy requirements within the cluster are met through a combination of rooftop solar installations, open access renewable energy procured from third-party providers and green power supplied by the state electricity board. The integrated approach has enabled the campus to sustain operational reliability while advancing environmental objectives. The licensed power distribution network within the campus supports stable energy delivery and creates economic benefits..
Waaree Renewable Technologies (Waaree) has signed a Letter of Award with its wholly owned subsidiary, Sunsational Power Private (SPPL), to develop a 300 megawatt (MW) and 450 megawatt peak (MWp) ground-mounted solar project. The company will provide engineering, procurement and construction services and two-year operation and maintenance services under the contract. The agreement covers the full EPC scope and a two-year O&M commitment. The scope will include site engineering, procurement of equipment and construction management across the installation. The project is scheduled to be completed ..
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Breakingviews – China renewables IPO plugs into upsides of a glut  Reuters
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Sunergise has completed the largest rooftop solar system currently operating in New Zealand, officially switched on a 5.3 MWp grid-connected PV system mounted across Fisher & Paykel Healthcare’s administration and manufacturing campus in Auckland.
Spanning approximately 70,000 square metres across two buildings and featuring 8,273 solar modules, the system is more than twice the size of the country’s previous largest rooftop array, the 2.3 MWp array installed by Sunergise at Mānawa Bay shopping centre at Auckland Airport.
The Fisher & Paykel project took nine months to build and was delivered under Sunergise’s SunPlus Power Purchase Agreement (PPA), meaning Fisher & Paykel Healthcare pays only for the electricity generated, with no upfront capital cost.
The completion of the project comes with New Zealand’s solar sector growing rapidly. Industry research suggests installed solar capacity will triple from 860 MW in 2026 to more than 2,100 MW by 2031, with commercial and industrial rooftop adoption accelerating as businesses seek to reduce electricity costs and meet sustainability targets.
Sunergise Chief Executive Officer Paul Makumbe said the Fisher & Paykel project sets a new standard for what is possible in New Zealand’s energy sector and serves as a replicable model for large energy users who want to lower energy bills and reduce their carbon footprint.
“This is a landmark project for New Zealand. A 5.3 MW system on the rooftop of one of the country’s most recognised companies shows what’s possible when businesses commit to clean energy at scale,” he said.
The new rooftop system is expected to generate more than 6,600 MWh of clean energy per year. It will also offset more than 486 tonnes of carbon dioxide annually.
Jonti Rhodes, vice president of supply chain, facilities and sustainability at Fisher & Paykel Healthcare, said the project shows what the renewable energy future looks like, adding that shifting a significant portion of the company’s energy consumption to solar power has already proven a smart business strategy.
“Investing in renewables is not only the right thing to do, it’s the smartest business strategy to implement,” he said. “Hopefully this serves as an example to other New Zealand businesses.”
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Brisbane-headquartered developer Renewable Energy Partners (REP) has broadened the scope of its Bogunda Energy Hub to incorporate solar photovoltaic panels and battery storage, moving the venture into preliminary development stages south of Hughenden in Queensland, Australia.
Initially unveiled in August 2024 as a 5GW wind farm, the scheme has been redesigned into a 1.85GW hybrid facility. This now includes 850MW of wind generation from roughly 136 turbines, 500MW of solar PV using over 714,000 panels, and a 500MW/2,000MWh battery energy storage system with a four-hour discharge duration.
REP has established a dedicated online platform for community engagement regarding the project. Ecological assessments and studies into grid connection alternatives are now underway.
Building activities are projected to generate approximately 300 positions within the Flinders Shire area, with at least 20 permanent roles after the facility becomes operational. The development phase is scheduled to continue until 2029, after which a three-year construction period is planned, aiming for commercial start-up in 2032. The project could be rolled out in phases.
The Bogunda Energy Hub falls within the proposed Stage 2 Flinders Renewable Energy Zone (REZ). Its location was deliberately chosen to leverage CopperString, Powerlink‘s intended high-voltage transmission line linking North West Queensland to the National Electricity Market (NEM). The site is described as being next to the CopperString corridor, which minimizes the requirement for new dedicated transmission infrastructure and offers a significant grid connection benefit compared to locations needing fresh line construction.
As PV Tech reported last week, the Queensland government allocated AU$3.2 billion (US$2.24 billion) to the CopperString transmission initiative in its 2026-27 state budget.
REP was established to initiate and advance large-scale renewable energy ventures in Australia, and it reports holding a pipeline of 10GW encompassing wind, solar, battery, and pumped hydro projects at various development stages.
Ben Larsson, REP’s head of origination, stated during the initial announcement that the sector had long recognized Hughenden’s wind potential, and with CopperString’s original concept becoming a tangible reality, REP was eager to collaborate with landowner partners to harness the area’s wind resources.
REP’s additional Queensland undertakings comprise the 500MW Wambo wind farm, the 1,078MWh Ulinda Park battery storage system co-developed with Akaysha Energy, and the 250MW Hopeland solar project alongside Pacific Partnerships. Also included are the 150MW/300MWh Western Downs Battery, linked to Powerlink’s Western Downs Substation, and the 500MW Yuleba wind farm developed with Cubico Sustainable Investments. Furthermore, REP is progressing the 750MW Capricornia pumped hydro project, which offers 16 hours of storage capacity, situated near Mackay and developed in partnership with Copenhagen Infrastructure Partners and CS Energy.
The Bogunda venture requires permits under Queensland’s State Code 23 of the State Development Assessment Provisions, evaluation under the EPBC Act, and the negotiation of a Community Benefits Agreement with Flinders Shire Regional Council.
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This report provides a comprehensive view of the static converter industry in Australia, tracking demand, supply, and trade flows across the national value chain. It explains how demand across key channels and end-use segments shapes consumption patterns, while also mapping the role of input availability, production efficiency, and regulatory standards on supply.
Beyond headline metrics, the study benchmarks prices, margins, and trade routes so you can see where value is created and how it moves between domestic suppliers and international partners. The analysis is designed to support strategic planning, market entry, portfolio prioritization, and risk management in the static converter landscape in Australia.
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This report provides a consistent view of market size, trade balance, prices, and per-capita indicators for Australia. The profile highlights demand structure and trade position, enabling benchmarking against regional and global peers.
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All data are normalized to a common product definition and mapped to a consistent set of codes. This ensures that comparisons across time are aligned and actionable.
The forecast horizon extends to 2035 and is based on a structured model that links static converter demand and supply to macroeconomic indicators, trade patterns, and sector-specific drivers. The model captures both cyclical and structural factors and reflects known policy and technology shifts in Australia.
Each projection is built from national historical patterns and the broader regional context, allowing the report to show where growth is concentrated and where risks are elevated.
Prices are analyzed in detail, including export and import unit values, regional spreads, and changes in trade costs. The report highlights how seasonality, freight rates, exchange rates, and supply disruptions influence pricing and margins.
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This report is designed for manufacturers, distributors, importers, wholesalers, investors, and advisors who need a clear, data-driven picture of static converter dynamics in Australia.
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Navitas Solar’s proposed solar cell facility is being designed as a highly automated production platform capable of supporting future technology upgrades and next-generation cell architectures.
June 16, 2026. By Abha Rustagi

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Brisbane-based developer Renewable Energy Partners (REP) has broadened the Bogunda Energy Hub to include solar photovoltaic panels and battery storage, with the venture now officially in its preliminary development phase south of Hughenden in Queensland, Australia. Initially unveiled in August 2024 as a 5GW wind farm, the scheme has been restructured into a 1.85GW hybrid facility consisting of 850MW of wind generation from roughly 136 turbines, 500MW of solar PV using over 714,000 panels, and a 500MW/2,000MWh battery energy storage system with a four-hour discharge duration.
REP has introduced a dedicated community engagement website for the project, while ecological surveys and grid interconnection feasibility studies are now underway. Construction is forecast to generate approximately 300 jobs within the Flinders Shire area, with 20 or more permanent operational roles after the facility becomes operational. The development phase is anticipated to last until 2029, followed by a three-year construction period aiming for commercial operation in 2032, with the possibility of phased delivery.
The Bogunda Energy Hub is located within the proposed Stage 2 Flinders Renewable Energy Zone (REZ) and has been deliberately sited to capitalize on CopperString, Powerlink’s planned high-voltage transmission line linking North West Queensland to the National Electricity Market (NEM). The project site is described as being next to the CopperString corridor, which minimizes the requirement for new dedicated transmission lines and offers a significant grid connection benefit compared to locations that would need fresh line construction. As reported by PV Tech last week, the Queensland government committed AU$3.2 billion (US$2.24 billion) to the CopperString transmission initiative in its 2026-27 State Budget.
REP was established to originate and develop large-scale renewable energy projects in Australia and states it holds a portfolio of 10GW of wind, solar, battery, and pumped hydro projects at various development stages. Ben Larsson, REP’s head of origination, remarked at the time of the initial announcement that the industry had long recognized Hughenden’s wind resource, and with CopperString’s original vision becoming a tangible reality, REP was eager to collaborate with landowner partners to harness the region’s wind potential.
REP’s other Queensland ventures include the 500MW Wambo wind farm, the 1,078MWh Ulinda Park battery storage system developed in partnership with Akaysha Energy, and the 250MW Hopeland solar project in cooperation with Pacific Partnerships. Additionally, there is the 150MW/300MWh Western Downs Battery, which connects to Powerlink’s Western Downs Substation, along with the 500MW Yuleba wind farm developed with Cubico Sustainable Investments. Furthermore, REP is advancing the 750MW Capricornia pumped hydro project, which offers 16-hour storage capacity, situated near Mackay and developed alongside Copenhagen Infrastructure Partners and CS Energy.
The Bogunda project requires approvals under Queensland’s State Code 23 of the State Development Assessment Provisions, assessment under the EPBC Act, and negotiation of a Community Benefits Agreement with Flinders Shire Regional Council.
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Intersolar Europe 2026 will be the stage chosen by Astronergy to present its latest innovations in photovoltaic technology, within a context marked by the global acceleration of the energy transition. From booth A1.380, the company will showcase its most advanced photovoltaic solutions, with special focus on the ASTRO N7 Pro series and the new ASTRO N7s 3.0, which will make its global debut during Intersolar Europe 2026. 
Astronergy’s participation at the exhibition will focus on technologies designed to maximize energy efficiency, reduce degradation, and enhance module reliability in both utility-scale and residential applications, aligning with some of the key technological trends shaping this year’s edition in Munich. 
Among the key solutions Astronergy will present at Intersolar Europe 2026 is the ASTRO N7 Pro, its latest flagship high-performance module series. The product is powered by TOPCon 5.0+ cell technology, 210R rectangular wafers, and a quarter-cut cell design, combined with high-density encapsulation to deliver high power output, high efficiency, strong reliability, high bifaciality, low degradation, reduced hot-spot risk, and an excellent temperature coefficient. 
The TOPCon 5.0+ cell technology integrates advanced innovations such as ASP, PF, SNOP, emitter passivation optimization, and hydrogen passivation, achieving multidimensional breakthroughs in passivation effect, light-capture capability, and bifacial power generation performance. As a result, cell efficiency increases by more than 0.7%. 
The quarter-cut design reduces internal cell current, lowering power losses caused by current flow and enabling a power increase of over 25 W. Combined with high-density encapsulation and 20BB technology, it eliminates gaps between upper and lower cells, increasing the active area by 0.81% and significantly improving resistance to micro-cracks. 
One of the key highlights of ASTRO N7 Pro, which Astronergy will emphasize at Intersolar Europe 2026, is its 85±5% bifaciality. Thanks to PF technology and high-resistance fine grids, the module achieves a maximum power per watt of 1.26 W, significantly enhancing rear-side power gain. 
The module also features a -0.26%/°C temperature coefficient, ensuring stable power output even in high-temperature environments. Thanks to the quarter-cut design, which reduces internal thermal losses, the module delivers a single-watt generation gain of 0.6%–1.2%. 
In terms of degradation, ASTRO N7 Pro limits linear degradation to ≤0.35%, further reducing lifecycle degradation by 1.45% thanks to its advanced technologies and lower operating temperature. 
Another key advantage is its excellent hot-spot resistance and improved shading performance. The module features a circuit design with more and shorter independent branches, improving energy generation under partial shading conditions. Compared with conventional half-cut modules, the quarter-cut design can increase power output by more than 20% under shading conditions. 
In addition, the quarter-cut design reduces operating current and significantly lowers hot-spot temperatures caused by reverse current when a sub-cell is shaded. Hot-spot temperatures can be reduced by approximately 30°C, further improving module safety and reliability. 
Astronergy will also highlight the ASTRO N7 Pro’s strong low-irradiance performance at Intersolar Europe 2026. Powered by TOPCon 5.0+ technology, the module improves low-irradiance performance by approximately 3.4% compared with BC products, delivering clear advantages in early morning and late afternoon generation, with a single-watt power gain of up to 6.05%. 
Another major highlight at Intersolar Europe 2026 will be the global launch of the ASTRO N7s 3.0, developed based on the latest TOPCon 5.0 cell technology and incorporating advanced technologies such as 20BB, black light redirecting film (LRF), and high-density encapsulation to further enhance module efficiency and reliability. 
The new module integrates 213R large wafers, half-cut cell technology, and high-density encapsulation, maximizing utilization of the cell spacing area and increasing the active area to further improve power generation capability. 
The TOPCon 5.0 cell technology in ASTRO N7s 3.0 integrates ASP, PF, SNOP, emitter passivation optimization, and hydrogen passivation, achieving multidimensional breakthroughs in passivation effect, light-capture capability, and bifacial power generation performance. 
Astronergy will also highlight the structural innovations of the ASTRO N7s 3.0 at Intersolar Europe 2026, including low-stress flexible interconnection technology, which enables a more uniform stress distribution and reduces the risk of hidden cracks. 
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NISE Maps 102 GW Floating Solar Potential Across India, Opening New Path For Clean Energy Growth – Report  SolarQuarter
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Korea University Develops World’s Most Efficient Inorganic Lead-Tin Perovskite Solar Cell [Reading Science]
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A team of Korean researchers has developed a world-class inorganic lead-tin perovskite solar cell that operates reliably even under high-temperature and high-humidity conditions. By simultaneously addressing the long-standing issues of compositional non-uniformity and durability—considered the biggest obstacles to the commercialization of next-generation solar cells—this innovation is expected to enhance the competitiveness of the next-generation solar energy market.
Korea University announced on June 16 that a research team led by Professor Lim Sanghyuk from the Department of Chemical and Biomolecular Engineering has successfully developed a high-efficiency, 100% inorganic lead-tin (Pb-Sn) perovskite solar cell using the Composition-Pinned Growth (CPG) technology.
Research paper images. (Above) Improvement of compositional and electrical uniformity of inorganic perovskite thin films using compositionally fixed growth (CPG) process. (Below) Performance enhancement of inorganic perovskite solar cells using compositionally fixed growth (CPG) process. Provided by the research team
Inorganic lead-tin perovskites are attracting attention as materials for next-generation solar cells because they possess an ideal bandgap for maximizing the conversion of solar energy into electricity. They also offer superior thermal stability compared to existing organic-inorganic hybrid perovskites.
However, during the formation of thin films, the differing crystallization rates of lead and tin caused excessive accumulation of tin on the surface. This led to compositional non-uniformity and oxidation, resulting in increased defects and limiting both the efficiency and long-term stability of the solar cells.
The research team addressed this issue by introducing the Composition-Pinned Growth technology, which accelerates solvent evaporation and crystallization processes simultaneously. This minimizes the time for atomic separation and ensures a uniform lead-tin composition throughout the thin film.
The research showed that the separation of lead and tin during crystallization was suppressed, significantly reducing surface oxidation and defect density. Additionally, non-radiative recombination within the solar cell was minimized, further improving photoelectric conversion performance.
The solar cell using this technology achieved a maximum power conversion efficiency (PCE) of 19.37% per unit cell. This is the highest performance reported to date for inorganic lead-tin perovskite solar cells.
Research team photo. (From left) Jin-Kyung Park, Research Professor, Department of Chemical and Biomolecular Engineering, Korea University (First Author), Hyung-Jun Lee, Integrated Master’s and PhD Program, Korea University (First Author), Sang-Hyuk Lim, Professor, Korea University (Corresponding Author), Fei Zhang, Professor, Department of Chemical Engineering, Tianjin University, China (Corresponding Author), Jin-Hyuk Heo, Professor, Tianjin University, China (Corresponding Author). Provided by Korea University
The study also demonstrated commercial viability. The team applied the process to a spray coating-based, large-area production method to fabricate a large solar module with an area of 64 cm², achieving a module efficiency of 17.03%.
The solar cell also exhibited excellent durability. Even after operating continuously for 1,000 hours in harsh conditions of 85°C and 85% relative humidity, the developed solar cells maintained approximately 87% of their initial efficiency.

Professor Lim Sanghyuk of Korea University stated, “This research demonstrates that precise control of the thin film growth pathway can resolve the compositional non-uniformity and oxidation issues in inorganic lead-tin perovskites,” adding, “We expect this to become an important foundation for the commercialization of next-generation solar devices that are both highly efficient and stable and can be produced on a large scale in the future.”
The results of this study were published in the international journal InfoMat in the field of materials engineering.
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Energy giant switches on first phase of $1.1 billion Texas solar farm set to power AT&T and Toyota  Yahoo Finance
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Brisbane-based developer Renewable Energy Partners (REP) has expanded the Bogunda Energy Hub to include solar PV and battery energy storage, with the project now formally in early-stage development south of Hughenden in Queensland, Australia.
Originally announced in August 2024 as a 5GW wind plant, the project has been reconfigured as a 1.85GW hybrid hub comprising 850MW of wind generation across approximately 136 turbines, 500MW of solar PV across more than 714,000 modules and a 500MW/2,000MWh, 4-hour duration BESS.
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REP has launched a dedicated community consultation website for the project, with ecology surveys and grid connection options studies now commencing.
Construction is expected to create around 300 jobs in the Flinders Shire region, with 20 or more ongoing operational roles following commissioning.
The development phase is expected to run through to 2029, followed by a three-year construction period targeting commercial operations in 2032. The project may be delivered in stages.
The Bogunda Energy Hub sits within the proposed Stage 2 Flinders Renewable Energy Zone (REZ) and has been positioned specifically to take advantage of CopperString, Powerlink’s planned high-voltage transmission line connecting North West Queensland to the National Electricity Market (NEM).
The project site is described as adjacent to the CopperString route, reducing the need for new dedicated transmission infrastructure and giving the project a material grid connection advantage over sites that would require new line construction.
As reported by PV Tech last week, the Queensland government has committed AU$3.2 billion (US$2.24 billion) to the CopperString transmission project in its 2026-27 State Budget.
REP was founded to originate and develop large-scale renewable energy projects in Australia and describes itself as having a portfolio of 10GW of wind, solar, battery and pumped hydro projects across various stages of development.
Ben Larsson, REP’s head of origination, said at the time of the original announcement that “the industry has known of Hughenden’s wind resource for a long time,” and that with CopperString’s original vision “an emerging reality,” REP was looking forward to working with landowner partners to utilise the region’s wind resource.
REP’s other projects in Queensland consist of the 500MW Wambo wind plant, the 1,078MWh Ulinda Park battery storage system developed in partnership with Akaysha Energy, and the 250MW Hopeland solar project in collaboration with Pacific Partnerships.
Additionally, there is the 150MW/300MWh Western Downs Battery, which connects to Powerlink’s Western Downs Substation, along with the 500MW Yuleba wind plant developed with Cubico Sustainable Investments.
Furthermore, REP is also undertaking the 750MW Capricornia pumped hydro project, featuring a 16-hour storage capacity, located near Mackay and developed in association with Copenhagen Infrastructure Partners and CS Energy.
The Bogunda project requires approvals under Queensland’s State Code 23 of the State Development Assessment Provisions, assessment under the EPBC Act and negotiation of a Community Benefits Agreement with Flinders Shire Regional Council.

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We’ve written for years about how much solar power potential countries have, how much onshore and offshore wind power potential countries have, and how much solar power growth is occurring in countries around the world — but what about offshore solar power potential? That was never really part of the equation. However, as floating solar PV has proven itself and grown to significant levels, some are having the sense to evaluate offshore solar power potential.
In one of the sunnier countries of Europe, Spain, researchers have tried to quantify how much solar PV power could be built offshore. (Admittedly, the country is probably not feeling very sunny or optimistic today, given that their team just tied Cape Verde 0–0 in the World Cup, but that’s another story.)
Researchers from the University of A Coruña determined that 4.45 GW to 6.48 GW of floating offshore solar PV power capacity could be developed off the coast of Spain. That much solar power capacity could provide the country with 6.2% to 9% of the country’s electricity demand based on September 2025 data.
The evaluation utilizes Spain’s Maritime Spatial Planning Plans (POEM), which came through Royal Decree 150/2023.
The full study, “Assessment of installable offshore solar power capacity in Spain based on maritime spatial planning,” was published in the Journal of Cleaner Production.
Note that aside from simply adding solar power potential, there are actual benefits to floating solar PV systems versus conventional land-based solar PV systems. The cooling effect of the water under and around the solar PV systems can boost electricity generation from the solar panels by 10.2%. Payback periods can range from about three to seven years.
What about offshore wind power? If you have offshore solar, you can’t have offshore wind, right? Actually, the researchers see them as being complementary rather than competing with each other. In fact, having both technologies in the water, they could share some electricity infrastructure and both could be more economical.
Featured image from SolarDuck.
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OMV Petrom has taken the final investment decision for Bulgaria's Gabare project, a photovoltaic plant of approximately 415 MWp paired with 600 MWh of battery storage, with an estimated investment of €300 million.
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St. Louis American
East St. Louis wants to turn a polluted property once owned by aluminum manufacturer Alcoa into a community solar project that could lower electric bills for thousands of residents.
Under the proposal, residents would pay a $50 annual subscription fee to receive credits on their electric bills, City Manager Robert Betts said.
Betts said the 15-megawatt solar farm would provide bill credits to about 2,000 low-income residents who pay the annual fee. Another 1,000 residents could save up to 50% on their electric bills.
Any excess energy would be used to power city buildings and potentially support future business development.
Construction is expected to begin this month and be completed next year. Betts said the city is still awaiting approval of an interconnection agreement from Ameren Illinois.
East St. Louis first proposed the project about 20 years ago during Betts’ first stint as city manager.
“We tried it way back then, thinking that the process for the cleanup would only take a few years, no more than five, but it’s taken 20-some years to get this done,” he said.
Now Betts is again serving as city manager and picking up where he left off.
“What can we do to pass some savings on to the citizens, which are low-income and struggling to make these monthly utility payments?” he said. “So that’s what really drove me to make sure that we start this project back up.”
Many East St. Louis residents live on fixed incomes, Betts said. According to U.S. Census data, 32% of residents live in poverty — about three times the national average. Twenty-three percent are seniors.
The city worked with Renewable Energy Evolution to develop the project through the Biden administration’s Solar for All program.
President Donald Trump’s administration clawed back some of that money, but company founder and CEO Brian Maillet said Illinois was able to move the funding into state accounts quickly.
“Illinois got a lion’s share of that money from the federal government because they already had this program in place, so the state of Illinois is the place to be right now for solar,” he said.
Maillet said his company will pay the city upfront to lease the land for the project, a move expected to generate more than $1 million in revenue for East St. Louis. The city would take ownership of the solar farm within seven years.
East St. Louis residents also must make up at least 30% of the workforce under the company’s contract.
“We’re going to be training folks, reeducating them and getting them ready for the green energy economy that’s happening right now,” Maillet said.
According to project officials, toxic heavy metals and radioactive materials remain buried just a few feet below the surface at the former Alcoa site, making a solar farm one of the few safe options for redevelopment.
Betts said the solar farm is one of several projects aimed at revitalizing East St. Louis, including new housing developments, infrastructure improvements and efforts to support a proposed expansion of Gateway Arch National Park onto the Illinois riverfront.
“We’re building housing developments throughout the city. We’re improving our infrastructure, so this is a good time to be a city manager in East St. Louis,” Betts said.
This article originally appeared here.
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Almost all the economic value in a crystalline silicon solar module is concentrated in one material. Silver accounts for just 0.03% of a panel’s mass, but, according to data presented by Dr. Andreas Obst, head of recycling at Fraunhofer CSP, a German solar research institute, it can be worth more than the glass, aluminum and silicon combined.
A standard crystalline silicon solar module weighs approximately 11.6 kg. Obst said glass accounts for 67.5% of that weight but yields only around $55 (EUR 34) per module at current prices. The aluminum frame – 12.7% by weight – yields around $375. The silicon cells, at 2.7% of module weight, generate roughly $62. The silver contacts, representing just 0.03% of module mass, are worth approximately $985 per module at the material prices cited by Obst.
“When you’re talking about recycling of solar modules, you should talk about silver recovery,” Obst said. “The silicon from the solar cells just accounts for roughly 2.7% of the weight of an individual module – it’s really not that much money which would come out of the solar cells itself.”
Modules installed during Europe’s subsidy-driven buildout in the late 2000s are approaching the end of their 20-year support periods. Drawing on German installation and subsidy data, Obst estimated that Germany alone could face approximately 600,000 metric tons (MT) of PV waste per year at the peak of that wave in the early 2030s.
A 2016 joint projection by the International Renewable Energy Agency (IRENA) and the IEA Photovoltaic Power Systems Programme (IEA-PVPS) put cumulative end-of-life PV volumes at between 1.7 million MT and 8 million MT globally by 2030.
Prof. Yansong Shen, director of the ARC Research Hub for Photovoltaic Reliability and Sustainability at the University of New South Wales, estimated that Australia alone would face approximately 1 million MT of cumulative end-of-life panels by 2035. In Australia, by Shen’s account, recycling infrastructure is nowhere near that scale, with current capacity largely focused on aluminum frames and glass. A credible national system, he said, could begin emerging within three to five years.
Silver value
Shen cited spot silver prices of around $68 to $69 per troy ounce at press time, up from roughly $20 two years earlier. Obst said part of that rise reflects growing PV industry demand and the absence of recycling infrastructure. He said the global PV industry consumed approximately 6,000 metric tons of silver in 2023, against world annual mine production of roughly 30,000 metric tons, citing data from the Silver Institute.
Specific silver consumption per unit of installed capacity has fallen from roughly 200 MT per gigawatt-peak in 2006 to under 30 MT per gigawatt-peak today, but total industry demand has risen with deployment volumes.
“Silver reserve is being used up in PV manufacturing sectors,” Shen told pv magazine. Without continued silver-thrifting, copper substitution, and large-scale recycling, he said, most currently known silver reserves could be consumed within 25 years.
Obst drew a comparison with the photographic industry, which at its peak consumed roughly 35% of global annual silver production but recovered more than 70% of what it used. “The PV industry is nowhere near that,” he said.
Silver in a PV module is not straightforwardly recoverable – it is finely dispersed through the cell metallisation and encapsulated in the laminate. Recovering it requires either a hydrometallurgical or pyrometallurgical process, said Obst. “To recover the silver you need more advanced techniques. It’s not that easy to recover as for example the aluminium frame, which you can just separate mechanically,” he said.
No commercial hydrometallurgical recyclers responded to requests for comment. Obst’s assessment, based on Fraunhofer CSP’s process development work, was that a dedicated hydrometallurgical line requires throughput of several thousand metric tons of solar cells per year to justify its capital cost – a view that could not be independently tested against commercial operators.
Mechanical separation
The most common approach in current commercial PV recycling facilities is mechanical separation. The method carries lower operating costs but Ko said it contaminates high-value material streams when it relies primarily on crushing and shredding.
“Once glass, silicon, metals, and polymers are reduced into mixed particles, contamination becomes a significant challenge regardless of the subsequent separation technology employed,” said Terry Ko, chief operating officer of California-based PV Circonomy.
Ko said PV Circonomy’s PV Circulator performs sequential layer-by-layer separation, preventing glass from being crushed into the silicon stream, and has achieved a 99.3% mass recovery rate by weight according to SGS certification cited by the company. Ko acknowledged that no industry-wide purity specifications for recycled PV silicon feedstocks currently exist, with downstream refiners developing their own acceptance criteria.
Obst agreed that mechanical processes face inherent limitations on silver recovery specifically – a view that could not be independently tested against commercial hydrometallurgical operators, none of which responded to requests for comment.
Thermal processing
Obst assessed thermal pyrolysis – an oxygen-limited thermal treatment that decomposes encapsulants – positively, drawing on a visit to a facility operated by Shinryo Corp., a Mitsubishi Chemical Group subsidiary that operates PV recycling plants in Japan. The Kitakyushu-based company’s process uses high-temperature treatment to break down encapsulants, enabling the recovery of glass and metals from end-of-life modules.
“After a pyrolysis process it simplifies subsequent separation of glass and silicon because the grain sizes of the material are very different,” he said.
At around $1,000/MT of PV waste, according to Obst, the process carries a significant cost premium over mechanical alternatives. French company ROSI Solar, which operates a commercial pyrolysis line in France and is scaling internationally, did not respond to requests for comment.
Recovering silicon at PV-grade purity faces two structural constraints, Obst said. Purification requires removing the phosphorus-doped emitter layer with hydrofluoric acid, a process that demands large quantities of the chemical and is costly at scale. The second constraint is the industry’s shift from p-type to n-type base material. “As the base dopant remains in the material, you would end up in materials that nobody wants today.”
A 2022 collaboration between Fraunhofer CSP and Fraunhofer ISE produced a passivated emitter and rear cell (PERC) with 19.7% efficiency from 100% recycled silicon, against 22% on virgin material in the same run. The project has not been publicly reported to have moved beyond the demonstration stage.
Missing modules
One anomaly remains unexplained. Despite subsidy-era installations approaching decommissioning age, Obst said PV waste volumes arriving at German recycling facilities have declined in recent years. Fraunhofer CSP attempted to trace the discrepancy through customs statistics but could not close the gap. “Where are those modules?” Obst said. “I have no idea.”
That uncertainty is the central problem for anyone planning recycling investment. Facilities will need to scale for a 2030s peak whose timing and magnitude remain unclear, then absorb years of lower throughput before volumes recover in the 2040s – a cycle that Obst said makes the business case difficult to model, let alone finance.
Obst suggested physical storage of incoming modules as one option to maintain stable processing throughput. Ko said PV Circonomy is developing a hardware-as-a-service model to deploy processing capacity closer to where modules are generated, and had held active discussions in Australia.
What the missing-modules anomaly ultimately underscores is a mismatch the IEA-PVPS noted as recently as May: solar recycling technology is advancing, but the economic infrastructure to deploy it at scale – and the waste volumes needed to make it viable – have not yet arrived together.
From pv magazine Global
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“This marks 2 quarters in a row where renewables have generated over 90% of New Zealand’s electricity.”
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New Zealand just posted one of its cleanest power quarters ever with a little help from Mother Nature.
In the first three months of 2026, renewables generated 94.5% of the country’s electricity, with solar output hitting a record high and making the nation’s future clean-energy targets look far more attainable, per the nation’s latest Energy Quarterly.
Those results represent a sharp rise from the 83.2% renewable share recorded in the same quarter last year, as New Zealand’s Ministry of Business, Innovation & Employment reported. Hydro, wind, and solar all played a role in the increase.
The quarterly report noted that solar generation reached a record 373 gigawatt-hours, aided by strong summer conditions and new capacity at projects the MBIE highlighted, including Pāmu Rā ki Whitianga and the Te Herenga o Te Rā project near Ōpōtiki. 
“A favourable mix of strong hydro inflows, increased wind output, and a 50% year-on-year increase in solar generation helped keep renewable electricity generation high this quarter,” MBIE domains manager Amapola Generosa said in a press release.
Even though net generation increased 1.9% from a year earlier, fossil fuel use fell sharply. Gas-fired generation fell 67%, coal generation fell 66%, and MBIE said planned outages at Huntly Power Station also contributed to lower coal use, the report noted.
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“Declining domestic gas production and ongoing global uncertainty continue to influence prices and supply across the wider energy system,” Generosa said of the fossil fuels market.
A power grid getting this much of its electricity from renewable sources means fewer air pollutants from burning coal and gas, less exposure to volatile fossil fuel markets, and a better chance of keeping electricity cleaner as demand rises.
Potential effects include more stable energy costs, better air quality, and a more resilient electricity system.
Due to its low reliance on fossil fuels, New Zealand was somewhat cushioned against the effects of the war in Iran.
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In June, the New Zealand’s Ministry of Foreign Affairs and Trade cautioned that “the impact of the Iran conflict, including petrochemical supply chain disruption and the jump in fuel prices in New Zealand,” is beginning to impact consumer confidence and domestic economic data.
However, Generosa said in the press release, “Fuel imports remained stable despite disruption to global shipping routes following the early March closure of the Strait of Hormuz.”

Generosa described the quarter as a milestone.
“This marks two quarters in a row where renewables have generated over 90% of New Zealand’s electricity, and the highest share for a March quarter since 1980,” she noted in the release.
Outside factors still play a major role for renewables, as Generosa alluded to.
“Overall, the results reflect the strong impact of weather on New Zealand’s electricity system, with high rainfall and wind conditions driving increased renewable generation,” she concluded.
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If we want farmland to stay farmland, we have to be open-minded about what farming looks like today, writes Abby Broedlin, vice president of asset management at Nautilus Solar Energy.
Abigail Broedlin is vice president of asset management at Nautilus Solar Energy.
America is losing farms, and it’s happening because families have run out of options. Across the country, farmers are facing a level of financial pressure that would have been hard to imagine a generation ago. Commodity prices can collapse overnight. Input costs keep climbing regardless of what the market does. And an energy supply chain entangled in global instability means a crisis halfway around the world can drive up a farmer’s fertilizer bill before the planting season even begins.
For many family farms, simply covering property taxes has become a struggle, let alone breaking even after months of hard work, investment and risk. The farms aren’t disappearing because farmers want to sell. They are disappearing because the math no longer works. If we want farming to remain a viable livelihood for generations to come, we must have an honest conversation about what modern farming requires. Stability matters. But too often, our conversations about farmland are locked in outdated assumptions about how land can and should be used.
That tension is especially visible in debates around solar energy. For years, the idea of placing solar on farmland has been framed as a threat to agriculture — energy versus food, development versus tradition. But that framing overlooks a more nuanced reality emerging across rural communities. Where policy allows, community solar projects can serve as the difference between recurring stabilizing income and not having a farm at all.
Lease payments from community solar projects can offset or fully cover property taxes, reducing a major fixed cost that exists regardless of whether a crop succeeds or fails. That predictable income allows farmers to weather bad years and plan for the long term rather than operating season to season.
From a community solar perspective, unlike large-scale energy projects designed to export power elsewhere, these projects are small, distributed generation that serve nearby homes, businesses and public institutions like schools and hospitals. According to the USDA Census of Agriculture, in 2024 the average American farm was approximately 460 acres. Community solar projects are typically placed on 16 to 60 acres, and farmers and developers often strive to use lower-yield or underperforming land. The rest of the land remains in agricultural use, under the same ownership, often with greater financial security than before.
The alternative options are often far less ideal. Without stable income, some landowners feel pressure to sell portions of their property outright to housing developments, industrial uses, or they make other permanent changes that remove the land from agricultural use altogether. Community solar offers a different path, one that allows farmers to retain ownership, maintain flexibility and keep land in the family for future generations.
Importantly, these projects are not permanent. Community solar leases typically last between 20 and 40 years. At the end of that lease, the land doesn’t have to disappear from agriculture. Panels are removed and recycled, and farmers can return the acreage to crop planting, renew the lease, or choose another use.
Critics are right to raise questions about land use. These are deeply personal decisions tied to identity, heritage and community appeal. But framing the issue as agriculture versus solar misses the larger picture. The real risk to farmland isn’t thoughtful, small-scale clean energy development, it is larger economic pressures that force families to make the tough decision to sell the land altogether.
Community solar won’t be right for every farm, and it shouldn’t be. But for many landowners, it offers something increasingly rare in agriculture — predictability. If we want farmland to stay farmland, we have to be open-minded about what farming looks like today. Supporting both food production and local energy on the same land may not be farming of the past, but it can be the future.
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Each of the 13 states in PJM, and the District of Columbia, have “fundamentally different regulatory structures, resource portfolios and politics,” FERC Chairman Laura Swett said. FERC will host a conference in July to identify potential reforms to PJM’s governance structure.
Google has worked to make its data centers flexible, the company’s global head of data center energy told Utility Dive, but it’s often faster and more cost effective to pay other customers to shift their electricity usage.
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Each of the 13 states in PJM, and the District of Columbia, have “fundamentally different regulatory structures, resource portfolios and politics,” FERC Chairman Laura Swett said. FERC will host a conference in July to identify potential reforms to PJM’s governance structure.
Google has worked to make its data centers flexible, the company’s global head of data center energy told Utility Dive, but it’s often faster and more cost effective to pay other customers to shift their electricity usage.
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ST. PAUL — University of Minnesota Extension will host a free agrivoltaics webinar, “Keeping the farm in ‘solar farm’: Agrivoltaic logistics,” at 7 p.m. July 14.
Solar energy sites on rural landscapes are raising concerns about taking agricultural land out of production, but they can be developed to prioritize ag production, known as agrivoltaics. Building an agrivoltaic site is a logistical puzzle involving specialized site prep, complex operations management, and long-term land stewardship.
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Representatives from Pivot Energy and Solar Collective are the guest speakers. They will discuss agrivoltaics from a solar developer’s perspective, moving beyond the “why” and diving into the “how” of designing, permitting and operating projects where solar and soil work in tandem.
The webinar is designed for farmers, solar developers, landowners, government officials and ag professionals interested in the future of dual-use land management.
Pre-registration is required to access the zoom link at z.umn.edu/farminsolarfarm
View past agrivoltaics webinars at z.umn.edu/avwebinarsplaylist/
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IW supervisors set to vote June 18 on final BESS ordinance  Smithfield Times
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VIVESCIA and Amarenco are developing eight ground-mounted photovoltaic plants on unused land in the Ardennes, Marne and Aube. The operation is expected to generate over €3 million for the cooperative over some 30 years, without any direct financial investment from the group.
VIVESCIA, an agricultural and agri-food cooperative group from northeastern France, and Amarenco, an independent power producer (IPP) specializing in photovoltaics, have announced a partnership covering eight ground-mounted solar plants. Each installation will exceed 500 kilowatt-peak (kWp) of industrial-scale capacity and will be located on unused land owned by the cooperative. VIVESCIA states it will commit no direct financial investment, with Amarenco bearing all associated risks and financing.
The projects span three departments in the Grand Est region: two in the Ardennes (Amagne and Attigny), four in the Marne (Matougues, Nuisement-sur-Coole, Somme-Tourbe and Sommesous) and two in the Aube (Châtres and Onjon). During the operating phase, the arrangement is expected to generate a value creation envelope of over €3 million for VIVESCIA, spread over approximately 30 years, according to figures provided by the parties. In the broader context of European solar expansion, OMV Petrom recently committed €300 million to the Gabare solar project in Bulgaria, highlighting the diversity of deployment models across the continent. The cooperative will provide support on land security, local consultation and on-site coordination.
Amarenco will manage the entire lifecycle of the plants — feasibility studies, administrative procedures, financing, construction, operations and maintenance, and end-of-life decommissioning. The developer will bear all risks associated with the projects. This model, in which the developer funds the investment in exchange for land access, limits the landowner’s financial exposure while providing long-term recurring revenues.
Founded in 2013, Amarenco operates primarily in France, Ireland, Spain, Portugal and Austria and claims more than 2,000 projects to date. In 2025, the company states it reached 650 MW of installed solar capacity. Since 2020, it reportedly raised nearly €500 million from investors and invests more than €0.5 billion annually, according to its own statements. It employs more than 200 people across Europe.
VIVESCIA reports revenue of €3.8 billion as of June 30, 2025 and employs 4,000 staff across 14 countries. The cooperative counts 9,000 farmer-members from northeastern France and collects an average of 3.5 million tonnes of grain per year across its territories. For the group, the partnership aims to combine asset monetization, renewable electricity production and local territorial footprint, in its own terms. Ground-mounted solar on idle land is gaining traction globally, with photovoltaics displacing other energy sources across multiple markets.
Amarenco deploys soil regeneration programs on its solar sites, aimed at restoring carbon absorption capacity, promoting biodiversity and improving water retention. These initiatives align, according to the company, with the “4 per 1000” initiative launched alongside the Paris Climate Agreement in December 2015. Pierre Guerrier, Head of Development France at Amarenco, highlights that small ground-mounted plants on idle land “promote local acceptance” and “facilitate connection to the public electricity grid.” Cédric Cogniez, Chief Operating Officer for Agricultural Activities and Cereal Value Chains at VIVESCIA, describes the model as “simple, secured and built for the long term.”
California-based EPC developer Renewable America is seeking a strategic buyer for nine late-stage community solar projects totaling 33 MWdc and 31 MWh of battery storage, targeting
Gas's share of the global electricity mix fell to 21.8% in 2025, according to Ember. Solar grew 17 times faster, accounting for around 75% of global electricity demand growth.
Clearvise AG has broken ground on the Tezze photovoltaic park in Vicenza province, northern Italy. With a capacity of 4.1 MWp and a 20-year government tariff premium, it is the fir

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Mars produces dust storms unlike anything on Earth. The largest of them, called planet-encircling storms, can grow from a regional disturbance to a veil of dust over the entire planet in a matter of weeks.
By Space Daily Editorial Team · Editorial process
Published June 16, 2026
Mars produces dust storms unlike anything on Earth. The largest of them, called planet-encircling storms, can grow from a regional disturbance to a veil of dust over the entire planet in a matter of weeks. In 2018, one of these storms turned day into a dim, reddish dark over NASA’s Opportunity rover, cut off the sunlight the solar-powered machine ran on, and ended a mission that had already lasted more than fourteen years.
Opportunity was built for ninety days. It lasted nearly fifteen years. The storm is what finally stopped it, though, as is often the way with these things, exactly how it delivered the final blow is not entirely certain.
The first warning did not come from the rover. On 30 May 2018, NASA’s Mars Reconnaissance Orbiter spotted a regional dust storm and alerted the team running Opportunity on the ground. Within days the storm had ballooned. It soon covered an area larger than North America, and then larger still, until it wrapped the whole planet. At its height, almost the entire surface was hidden, with only the summit caldera of Olympus Mons, the tallest volcano in the solar system, standing above the dust.
These storms grow through a feedback loop. Airborne dust absorbs sunlight and warms the surrounding air. The warm air rises, pulling in wind, and the wind lifts more dust, which warms more air. A storm that starts in one region can feed on itself until it spans the globe.
What is not well understood is why some Martian years produce a planet-encircling storm and others do not. They arrive irregularly, every few Mars years, without a reliable schedule, which makes them hard to forecast far in advance.
Opportunity drew its power from solar panels, which on a clear Martian day generated enough electricity to drive, run instruments, and keep the rover warm. Dust takes that away in two ways: it blocks sunlight in the air, and it settles on the panels.
Engineers track how much sunlight the dust blocks using a figure called tau, a measure of atmospheric opacity. At Opportunity’s location on the rim of Endeavour Crater, tau normally sat around 0.5. During the storm it climbed to a recorded value of roughly 10.5 to 10.8, among the highest ever measured on Mars. The rover needed tau below about 2 to gather enough light to charge its batteries. It was getting a small fraction of that.
Science operations were suspended on 8 June. The last signal arrived on 10 June 2018, a partial image and a reading showing the batteries down to about 21 or 22 watt-hours, just enough to tell the team the rover was about to drop into a low-power state in which everything but its clock shut off. Then it went quiet.
The storm cut the power.
What happened next, over the months that followed, is where the certainty runs out. NASA kept trying. Over that period the agency sent more than a thousand commands, hoping that once the skies cleared the panels would catch enough light to wake the rover, and that a windy season late in 2018 might even blow the dust off them. Nothing came back. On 13 February 2019, NASA declared the mission complete. The most likely explanations are that dust coated the panels too thickly, or that the long stretch of cold and darkness during hibernation left the batteries or electronics unable to recover. Which of these it was cannot be confirmed from a rover that never spoke again.
A common picture needs correcting here. Mars storms are often imagined as violent gales that could knock a spacecraft over, an image helped along by films. The reality is close to the opposite. Mars’s atmosphere is about one per cent as dense as Earth’s. Even a fast Martian wind would push with only a small fraction of the force of a comparable wind on Earth.
The danger is not the push of the wind. It is the dust: what it does to sunlight, and what it does once it settles on a surface. For a solar-powered machine, that is the whole problem. The storm did not blow Opportunity over.
It starved it.
The contrast with Mars’s nuclear-powered rovers is the clearest lesson. While the 2018 storm was darkening the sky over Opportunity, NASA’s Curiosity rover was working through the same dust on the other side of the planet, slowed but not stopped. Curiosity does not rely on sunlight. It carries a small nuclear power source, a radioisotope generator, that produces electricity regardless of the weather.
The newer Perseverance rover is powered the same way, for the same reason. Solar power is lighter and cheaper, and it served Opportunity well for fourteen years, but it leaves a machine exposed to exactly the event that ended this one. The lander InSight, also solar-powered, met a slower version of the same fate, its panels gradually buried under accumulating dust until it fell silent in 2022.
Opportunity was meant to last ninety days and drive perhaps a kilometre. It lasted more than fourteen years and drove about forty-five, a record for any vehicle on another world. The storm that ended it was not a freak. Planet-encircling storms are a normal, if irregular, feature of the Martian climate, and another one will come. The open question for anything that has to survive on the surface, robot or eventually human, is the same one Opportunity ran into: how to keep the power on when the planet puts out the sun.
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Indian PV manufacturer Bluebird Solar has launched a new range of G12R n-type TOPCon bifacial PV modules targeting utility-scale, commercial and industrial (C&I), and rooftop solar applications.
The new module series offers power outputs of up to 630 W and module efficiencies of up to 23.32%.
The modules are based on n-type TOPCon cell technology and G12R rectangular wafers, enabling integration of a higher number of cells within a compact design to increase power density and optimize space utilization, the manufacturer said.
The bifacial glass-to-glass module features 132 half-cut cells with 16 busbar technology and is backed by a 12-year product warranty and 30-year power output warranty.
“Our new G12R module has been engineered to meet the evolving needs of modern solar projects by delivering higher energy yield, lower degradation, and better project economics,” said Akshay Mittal, director, Bluebird Solar.
“As the industry moves rapidly toward high-efficiency n-type solutions, our focus remains on providing advanced modules that offer superior performance, reliability, and long-term value for our customers,” added Rohit Tikku, CEO, Bluebird Solar.
Bluebird Solar currently operates a fully automated 2.5 GW PV module manufacturing facility in Greater Noida, Uttar Pradesh, producing high-efficiency mono PERC and n-type TOPCon solar modules for residential, commercial, industrial, and utility-scale applications.
From pv magazine India
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