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Huawei Digital Power, the energy technology business unit of Chinese technology group Huawei, has notified customers of planned price increases of 5% to 15% across several solar and energy storage product lines.
In a customer notice dated Oct. 20 and reported by Chinese industry media on Oct. 29, the company outlined proposed increases of 5% to 15% for residential solar-plus-storage products, commercial and industrial (C&I) systems, and utility-scale PV inverters and related equipment. Grid-forming utility-scale energy storage solutions, including power conversion systems (PCS), face smaller increases of 5% to 10%.
Huawei Digital Power said it had absorbed some of the additional manufacturing costs through internal efficiency measures but could no longer maintain existing prices without compromising product quality, delivery reliability or service commitments.
The company did not specify an implementation date, saying price adjustments would be negotiated individually with customers.
Huawei attributed the planned increases to rising prices for commodities, printed circuit boards (PCBs) and memory components since 2025. Copper is widely used in power electronics equipment, including busbars, cables, magnetic components and transformers, while PCBs and semiconductors are essential to inverter control and power conversion systems.
Copper prices have risen sharply in 2026. London Metal Exchange cash copper prices exceeded $14,700 per metric ton in mid-October, according to market data compiled by the International Copper Association Australia. Higher prices and tighter supplies of electronic components have added to procurement pressures for equipment manufacturers.
Huawei Digital Power is the latest in a series of Chinese inverter and energy storage equipment suppliers to announce price increases since August.
In September, Sungrow notified customers of price increases of 5% to 15% for PV inverters, storage converters and energy storage systems, effective Sept. 20. The company announced increases of 5% to 10% for its string, modular and matrix inverter ranges, and 10% to 15% for medium-voltage grid-connected models.
Growatt subsequently announced increases of 5% to 10% for string inverters, storage inverters and battery systems, effective Oct. 8. KSTAR also notified customers of increases of approximately 10% to 20% for selected energy products.
In August, Inovance Technology announced increases of 5% to 15% for energy storage power conversion equipment and related products. Kehua Digital Energy followed on Oct. 29 with increases of 5% to 15% across its product portfolio, effective Nov. 1.
The announced increases for inverters and power conversion systems contrast with continued pricing pressure in China’s solar module market. Industry pricing data showed further declines in some module quotations in October, reflecting differences in supply-demand conditions and manufacturing cost structures between solar modules and power electronics.
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Tuesday, November 10, 2026
5:00 pm – 6:00 pm CET, Berlin, Paris, Madrid
The new issue of pv magazine Global is out now!
Available in print and digital – get your copy today!
Day 1 | Europe’s Solar and Storage Markets 2027: What works where?
Day 2 | Solar + Storage Co-location: Three markets, three business cases
Day 3 | Solar Quality: Which technical risks still need better answers?
Day 4 | Cybersecurity and Procurement: What can European solar projects source in 2027 and beyond?
Thursday, November 5, 2026
10:00 am – 11:00 pm CEST, Berlin, Paris, Madrid
Friday, November 13, 2026
10:00 am – 11:00 am CET, Berlin, Paris, Madrid
As a media partner of Genera 2026, pv magazine will organize and moderate a session in Spanish in Madrid, during International Electrification and Decarbonization Week.
Monday, November 23, 2026
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Australian large-scale solar plants produced 5,100 GWh of clean energy last month, a 2% decline from the 5,200 GWh recorded in October 2025, according to Rystad Energy. The global energy consultancy reported that Western Australia was home to two of the three best-performing utility photovoltaic assets for the month.
The 100 MW Merredin Solar Farm, owned by Indonesian developer Sun Energy, was the top-performing large PV facility for the month. Rystad Senior Analyst David Dixon said the plant delivered an average AC capacity factor of 35%.
Naturgy‘s 128 MW Cunderdin Solar Farm in Western Australia ranked second with an average capacity factor of 32%. Pacific Partnerships‘ 102 MW Glenrowan Solar Farm in Victoria placed third, also at 32%, while stages one and two of Acen Australia‘s 400 MW Stubbo solar project in New South Wales took fourth and fifth places respectively.
Dixon said all Australian utility-scale PV and wind assets generated 5.1 TWh of clean energy last month, down 2% from 5.2 TWh in October 2025.
Victoria was the largest single state contributor to the monthly total, generating 290 GWh from utility-scale solar and 1,130 GWh from wind, for a combined 1,420 GWh.
The leading wind assets for the month were the Flat Rocks wind farm in Western Australia at a 48% capacity factor and Warradarge, also in Western Australia, at 47%. Clarke Creek stage 1b in Queensland ranked third at 44%.
Dixon noted that on a trailing 12-month basis, both the number of hours of negative prices and the volume of curtailed utility solar and wind generation are starting to decline as utility battery capacity comes online. He said the trend is expected to continue over the next 24 months as the National Electricity Market utility battery fleet expands from the current 26 GWh to almost 60 GWh by the end of 2028.
Dixon also noted that gas generation in the National Electricity Market totalled 426 GWh for October, the lowest for that month since the market began.
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Agricultural solarisation offers 116 GW opportunity for India’s domestic solar manufacturing industry: ISMA  ANI News
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The forage experiment used observations from the 2022 and 2023 growing seasons, comparing plots beneath solar installations rated at 30 kW and 50 kW with an unshaded control. Researchers kept all experimental plots ungrazed to maintain consistent treatment conditions. They tested alfalfa, field peas, meadow fescue, orchard grass, red clover, brown midrib sorghum-Sudan grass and white clover, alongside three grass-legume mixtures containing alfalfa, red clover or white clover. Harvesting took place three times in each year, once plants were approximately 25–35 cm tall, the recommended height before grazing by lactating dairy cattle. The samples were then assessed for nutritional quality.
The 50-kW installation cast more shade and produced less forage biomass than either the smaller installation or the full-sun plot. Its forage nevertheless ranked highest for nutritional value. Material from beneath one or both installations matched or exceeded the comparison forage in crude protein and the digestibility of fibre across the digestive tract. For subsequent grazing experiments involving solar arrays, the researchers recommended measuring soil moisture and temperature directly to help establish the mechanisms behind the observed forage responses. The team has also been examining crops beneath and outside an array installed in 2020.
Earlier work examined how shade affected dairy cattle. Between June and September 2019, researchers randomly divided 24 cows between neighbouring paddocks, one shaded and the other unshaded, while daytime air temperatures ranged from 27°C to 34°C. They recorded behaviour, analysed milk and used Smaxtec boluses and CowManager ear tags to track body temperature, activity and rumination. Published in the Journal of Dairy Science in 2021, the results showed afternoon breathing rates of 66.4 breaths per minute among shaded cows, compared with 78.3 among those without shade. Internal temperatures were also lower in the shaded group from 10am until 8pm. The groups had comparable fly prevalence, milk output, milk-fat and protein percentages, and rates of water consumption. The researchers concluded that agrivoltaics offered potential to reduce farms’ carbon footprints and heat-stress risks for grazing dairy cows.
A 240-kW solar installation was added to the centre’s existing shaded pasture in 2020. It supplied electricity to a rapid-charging facility for utility vehicles. According to Heins, the panels were positioned 2.4–3 metres above ground to keep them beyond the cows’ reach, with little additional expense arising from the elevation. The panels and associated electrical infrastructure cost approximately US$90,000 (€70,000). The project was designed to support investigations into layouts that could shelter grazing livestock from summer sunshine and serve as windbreaks or snow fences during winter. With the installation operating, researchers could measure power generation and calculate investment returns.
The team’s planned work also covered solar-tracking equipment, suitable forage species, cattle reproduction and longer-term changes in milk output and composition, weight, body condition and health. Heins and his colleagues wanted to model and test ways of changing panel orientation during the day, either manually or automatically. He said the research was intended to produce recommendations for farmers, with economic findings that would encourage adoption of photovoltaic equipment. Following delays to the panel research, the team is installing another solar system at the centre. It will combine automated sun tracking with vertically mounted panels that researchers can test as cattle windbreaks.
Since 2020, the researchers have collected annual observations on the weight, body condition, health and welfare of cattle grazing in the two neighbouring experimental paddocks. Heins said the lower internal temperatures of cattle grazing beneath the panels had persisted in each year’s observations. These measurements extend the earlier work on shade and heat stress, alongside the team’s continuing investigations of forage production around the solar installations.
Heins said farmers assessing returns from a pasture-based solar installation should include both electricity generation and livestock operations in their calculations. In his account, electricity revenue covers the panels, while retaining agricultural use of the ground provides further benefits. Cows consume pasture grown beneath the equipment during summer, reducing feed costs and the need to supply stored feed. Grazing also controls vegetation around the installation, avoiding the expense of hiring someone to cut the grass, as happens at many solar sites. Heins said the combined income from livestock and solar generation increased revenue from land used for both activities.
The Dairy News holds a prominent position as a global authority in the milk market.
As the one of the world’s major specialized media outlets for the dairy industry, The Dairy News is a highly influential and authoritative source. This independent media platform delivers numerous daily news updates on the global state of the dairy industry.
Not only a news provider, The Dairy News is a key organizer of significant events in the global dairy market, including the prestigious Dairy Olympics, Dairy Rally, Central Asia Dairy Congress etc.
Guided by principles of openness, accessibility, and independence, The DairyNews ensures that all information regarding dairy farming, the dairy industry, and the activities of market players is freely accessible to its readers.
In a move to further contribute to industry insights, The DairyNews is set to launch an independent analytical platform—the Dairy Intelligence Agency (DIA). The analytical products from DIA include the Dairy Maps, featuring operational and regularly updated information about dairy industry enterprises, and the Milk Shortage Maps, an annual analytical tool assessing regional self-sufficiency levels.
With a readership exceeding 4,5 million unique visitors and garnering over 10 million views annually, The DairyNews continues to play a pivotal role in disseminating vital information within the dairy sector.

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How to Apply for Rooftop Solar Subsidy in India: Step-by-Step Guide  LiveChennai
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Poland’s Energy Regulatory Office (URE) has published the schedule for the 2026 renewable energy auctions, with a total budget of approximately (PLN 24.9 billion ($6.34 billion) covering over 76 TWh of renewable electricity.
The auctions for solar PV and onshore wind projects will take place on November 9–10, divided into two capacity categories: installations up to 1 MW and those above 1 MW.
The procurement exercises will be open exclusively to new installations, with bids evaluated solely on price. Developers must obtain an auction admission certificate through the Online Auction Platform (IPA) to participate.
Poland’s renewable energy auctions have been dominated by solar projects in recent years, with limited participation from onshore wind developers. In the 2025 auction round, the regulator awarded approximately 1.67 GW of solar capacity and 82.7 MW of wind capacity, with PV accounting for 178 of the 181 successful bids. Solar bid prices ranged from PLN 216.90/MWh to PLN 374.77/MWh across the two capacity categories.
A similar trend emerged in 2024, when solar secured 198 of 200 winning bids, compared with just two wind projects totaling 90.8 MW. Auction participation has nevertheless remained relatively subdued, with developers increasingly exploring corporate power purchase agreements (PPAs) and merchant electricity sales as alternatives to government-backed support, a trend also highlighted following the 2023 auctions.
The auctions form part of Poland’s 2022–2027 renewable energy support framework, which originally targeted approximately 9 GW of new solar capacity and 3 GW of onshore wind.
Poland installed 3.6 GW of solar in 2025, according to data collected by Agencja Rynku Energii (ARE) on behalf of the country’s Ministry of Energy. The figure is down on the 4 GW of solar added in 2024 and takes cumulative solar capacity to 24.8 GW.
Separate data collected by Poland’s lone transmission system operator, Polskie Sieci Elektroenergetyczne (PSE), says total solar capacity was as high as 25.5 GW by the end of last year. Grzegorz Wisniewski, founder and director of the Institute for Renewable Energy (IEO), explained to pv magazine that the discrepancy is likely caused by some large PV farms that were connected to the grid in December being included in PSE’s figures, while ARE’s data will account for them in 2026.
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Tuesday, November 10, 2026
5:00 pm – 6:00 pm CET, Berlin, Paris, Madrid
The new issue of pv magazine Global is out now!
Available in print and digital – get your copy today!
Day 1 | Europe’s Solar and Storage Markets 2027: What works where?
Day 2 | Solar + Storage Co-location: Three markets, three business cases
Day 3 | Solar Quality: Which technical risks still need better answers?
Day 4 | Cybersecurity and Procurement: What can European solar projects source in 2027 and beyond?
Thursday, November 5, 2026
10:00 am – 11:00 pm CEST, Berlin, Paris, Madrid
Friday, November 13, 2026
10:00 am – 11:00 am CET, Berlin, Paris, Madrid
As a media partner of Genera 2026, pv magazine will organize and moderate a session in Spanish in Madrid, during International Electrification and Decarbonization Week.
Monday, November 23, 2026
11:00 am – 12:00 pm CEST, Berlin, Paris, Madrid

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India’s renewable energy capacity is projected to reach around 530 GW by 2030, driven primarily by solar power, which is expected to account for more than 80% of the capacity additions, according to the IEA.
The country’s renewable energy expansion has positioned it as the world’s second-fastest-growing renewable energy market and the second-largest manufacturer of solar photovoltaic (PV) modules. India’s renewable power capacity surpassed 300 GW in the fourth quarter of 2026, nearly quadrupling over the past decade.
The country also achieved its target of sourcing 50% of its installed power capacity from non-fossil fuel sources in 2025, five years ahead of schedule. In addition, India has emerged as the world’s fourth-largest liquid biofuel market, with production increasing sixfold between 2020 and 2025.
According to the IEA, sustained policy support, investment in renewable energy infrastructure and long-term planning have contributed to India’s growth in the clean energy sector.
The IEA noted that India’s renewable energy expansion is also reducing its dependence on imported fossil fuels. Without the solar PV, wind and bioenergy capacity added since 2010, coal imports in 2025 would have been approximately 110 million tonnes higher, while the import dependence of electricity generation would have exceeded 30%, nearly twice the actual level.
Renewable electricity helped India save more than USD 100 billion in cumulative coal and natural gas import expenditure between 2011 and 2025. These savings are expected to more than double by 2030.
Solar PV is expected to remain the primary driver of India’s renewable energy growth, with installed capacity projected to exceed 350 GW by 2030. Wind capacity is expected to approach 90 GW, while hydropower capacity is forecast to reach 75 GW.
Renewable electricity generation exceeded 500 TWh in 2025, accounting for around one-quarter of India’s total electricity supply. The IEA projects this figure to approach 950 TWh by 2030, meeting approximately 35% of the country’s electricity demand.
Solar PV overtook hydropower as India’s largest source of renewable electricity in 2025 and is expected to contribute more than half of renewable generation by 2030.
The share of variable renewable energy, including solar and wind, in India’s electricity supply is projected to increase from around 14% to approximately 26% by 2030. This is expected to increase the requirement for grid infrastructure, energy storage and power system flexibility.
Distributed solar PV capacity for self-consumption is projected to triple to more than 100 GW by 2030, supported by residential rooftop installations and commercial and industrial demand.
The PM Surya Ghar Muft Bijli Yojana is accelerating residential rooftop solar adoption, while PM-KUSUM is supporting the solarisation of agricultural feeders and irrigation pumps.
Corporate renewable energy procurement is also expected to become a significant source of demand. Corporate power purchase agreements are projected to support around 20% of utility-scale solar and wind capacity additions by 2030, aided by reforms in open-access renewable energy procurement.
India’s solar PV manufacturing capacity reached approximately 225 GW in September 2026 and is expected to increase further by 2030, strengthening its position as the world’s second-largest solar module manufacturer.
The IEA highlighted the role of industrial policies, including the Production Linked Incentive (PLI) scheme and domestic sourcing requirements, in attracting investments into solar manufacturing.
India is also targeting strategic upstream segments of the solar PV supply chain, where global dependence on imports from China exceeds 95%. Its wind manufacturing industry is expanding as well, with the country projected to become the world’s second-largest wind equipment manufacturer by 2030.
Despite the progress in renewable energy deployment, the IEA identified grid infrastructure, energy storage and power system flexibility as important requirements for India’s next phase of growth.
Faster transmission expansion, improved forecasting and dispatch systems, increased energy storage deployment and greater flexibility from conventional power plants will be required to integrate higher shares of variable renewable energy.
The report also highlighted the need to improve the financial position of distribution companies (DISCOMs), streamline land acquisition and permitting processes, and reduce project execution delays, particularly for wind and hydropower projects.
Addressing these challenges could accelerate renewable power capacity deployment during 2026-2030 by more than 20%.
The IEA also called for more efficient and extensive feedstock supply chains, supported by sustainability standards, to accelerate the adoption of biogas, biofuels and solid bioenergy.
India’s renewable energy expansion is expected to remain central to its energy security objectives and its longer-term ambition of achieving net-zero greenhouse gas emissions by 2070.
We are India’s leading B2B media house, reporting full-time on solar energy, wind, battery storage, solar inverters, and electric vehicle (EV)
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The Autumn issue of 2026 is available now! The new issue begins with a regional report on Asia Pacific, looking at the region’s transition from building capacity to building systems. The issue also explores topics such as offshore wind foundations, solar maintenance, training the new workforce, inspection & maintenance, and more! With insights from experts such as Everllence, BW Ideol, EM&I, Watson Farley & Williams, and many more, make sure to check out this issue now.
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Sungrow has completed the grid connection and commissioning of the 1243 MWh Hams Hall battery energy storage system project.
Sungrow, a globally leading photovoltaic (PV) inverter and energy storage system provider, has completed the commissioning of what is expected to be Europe’s largest operational battery energy storage system (BESS) at Hams Hall in the West Midlands, the UK, in partnership with global energy storage owner-operator, BW ESS. The 350 MW/1243 MWh project, powered by Sungrow’s PowerTitan 2.0 technology, progressed from grid connection to commercial operation in 20 days, demonstrating exceptional speed of project delivery and commissioning.
Located adjacent to National Grid’s Hams Hall substation, this new project will play an important role in balancing electricity supply and demand, supporting the integration of renewable energy into the UK’s electricity system and strengthening grid resilience.
The delivery of the first phase of Hams Hall within 20 days was made possible through:
Direct access to technical expertise: Sungrow deployed dedicated BESS engineers directly to site, enabling technical challenges to be investigated and resolved with immediate input from the teams responsible for the technology. This reduced reliance on remote escalation and supported faster decision-making during critical commissioning activities.
Thorough preparation before hot commissioning: During the initial warm commissioning phase, the team prioritised fault identification and chiller operation, addressing potential technical issues before hot commissioning began. Dedicated operational technology engineers were also present throughout hot commissioning, providing immediate support for system integration and operational troubleshooting.
Close customer-headquarters co-ordination: Customer representatives were present on site almost daily and established escalation channels to Sungrow’s headquarters, both teams were able to address outstanding issues quickly, maintain momentum, and minimise delays between commissioning activities.
Together, these measures enabled the teams to complete hot commissioning and delivery, supporting the project’s rapid progression towards commercial operations.
James Li, Vice President, Europe at Sungrow, responded: “Delivering a battery storage project of this scale depends on the ability to bring together engineering expertise, careful preparation, and close collaboration at every stage. At Hams Hall, our teams worked directly alongside BW ESS to identify and resolve challenges quickly. This achievement demonstrates how the right technical support and strong partnerships can accelerate the delivery of critical energy infrastructure as the UK expands its renewable energy capacity.”
Nan Jia, Chief Technology Officer at BW ESS, added: “Moving a 1243 MWh system from grid connection to commercial operation in 20 days is a remarkable result, and it was only possible because BW ESS and Sungrow treated this as a shared engineering challenge. Following our work together at Bramley, Hams Hall shows what this partnership can deliver at scale. Projects like this are critical to the UK’s transition to a cleaner, more resilient energy system.”
Hams Hall represents a significant addition to the UK’s growing battery storage infrastructure. As more renewable energy comes onto the electricity grid, large scale storage projects are becoming essential to managing fluctuations in generation and demand, helping maintain a reliable and resilient electricity system.
The project is expected to expand further in its second phase, increasing total capacity to 400 MW/1424 MWh. At full capacity, BW ESS estimates it will be capable of supporting the electricity needs of approximately 1.3 million homes for up to 3.5 hours.
The project also builds on Sungrow’s ongoing collaboration with BW ESS in the UK, including the Bramley BESS project in Hampshire. The continued partnership reflects BW ESS’ confidence in Sungrow’s energy storage technology, engineering delivery capabilities, and dedicated on-site technical support. Through its PowerTitan energy storage technology and dedicated engineering support, Sungrow continues to support the deployment of utility scale storage projects that strengthen energy security and enable the UK’s transition to a cleaner energy system.
For more news and technical articles from the global renewable industry, read the latest issue of Energy Global magazine.
The Autumn issue of 2026 is available now! The new issue begins with a regional report on Asia Pacific, looking at the region’s transition from building capacity to building systems. The issue also explores topics such as offshore wind foundations, solar maintenance, training the new workforce, inspection & maintenance, and more! With insights from experts such as Everllence, BW Ideol, EM&I, Watson Farley & Williams, and many more, make sure to check out this issue now.

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Envision Group, a green energy technology group, has announced that its integrated 800 V high-voltage DC (HVDC) power supply system has entered commercial operation at the Xinghe AI data center base in Ulanqab. The company describes it as the world’s first system of its kind to operate commercially at a large-scale AI data center (AIDC). According to local media, the system comprises Envision’s Tianshu controller, solid-state transformer (SST), DC energy storage, and DC/DC units. It converts 10 kV AC power to an 800 V DC bus, with millisecond-level coordination between the SST and energy storage to respond to fluctuations in GPU training loads.
Envision launched its AIDC power system in June 2026, integrating wind, solar, and storage with SSTs, 800 V DC distribution, and AI-based dispatch. Its 2.5 MW SST accepts 10/13.8 kV AC input and has a stated maximum conversion efficiency of 98.5%. The solution pairs lithium iron phosphate (LFP) storage for more than two hours of backup power and energy shifting with sodium-ion storage for rapid power smoothing.
China added 31 GW/84 GWh of new-type energy storage capacity in the first nine months (9M) of 2026, according to cumulative figures published by the National Energy Administration (NEA). At its Q3 press conference, the NEA reported that cumulative installed capacity reached 167 GW/435 GWh by the end of September, up 63% year on year, with average storage duration extending to 2.61 hours.
Solar additions, by contrast, slowed sharply during 9M 2026. Newly grid-connected PV capacity totaled 110.32 GW, comprising 45.80 GW of utility-scale and 64.52 GW of distributed installations, down approximately 54% from around 240 GW in the same period of 2025. Cumulative PV capacity reached 1.31 TW. Solar generation totaled 1,064.2 TWh, with a utilization rate of 93.1%.
Concentrated solar power (CSP) added 500 MW during the same period, bringing cumulative capacity to 2.32 GW. Generation reached 1.456 TWh.
Hunan Provincial Development and Reform Commission has launched its 2026 mechanism price auction for wind and solar projects, covering 2.286 TWh of electricity. Eligible projects must reach full-capacity operation between June 1, 2025, and December 31, 2027. Only distributed PV projects are eligible in this round; large-scale C&I distributed PV projects and projects intended for local consumption are excluded.
The total volume comprises 1.19 TWh for wind and 1.096 TWh for solar PV. Both technologies have a bidding price range of RMB 0.23-0.35/kWh, with the mechanism price applying for 10 years.
Recently, Hunan issued a trial implementation plan allowing virtual power plants (VPPs) to participate in electricity market trading (see China Solar PV News Snippets).
Shanghai-based energy developer Shenergy has released the results of its 2026-2027 PV module framework procurement tender, covering an estimated 1 GW of solar modules. The framework agreement will run from the signing date through December 31, 2027. The tender called specifically for n-type PV modules (TOPCon and BC), with deliveries required within a month of the signing of the contract (see China Solar PV News Snippets).
According to local media, LONGi ranked first with a bid of RMB 0.785/W, followed by Jinko at RMB 0.787/W and Tongwei at RMB 0.770/W.
TaiyangNews 2024

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India’s solar manufacturing industry could transform into a fully integrated global powerhouse by 2047, creating 32.3 lakh direct and indirect jobs, attracting $89 billion in manufacturing investments and eliminating its solar import bill, according to a report by the Indian Solar Manufacturers Association (ISMA).
Titled Vision 2047: Solar Manufacturing from Polysilicon to Power Plant, the report outlines a roadmap to move beyond module assembly and establish manufacturing capabilities across the entire solar value chain—from polysilicon and ingots to wafers, cells and modules. The transition could enable India to retain a significantly larger share of the value generated by every solar panel manufactured domestically while strengthening its position in global markets.
Under the current-policy scenario, ISMA projects India’s installed solar power generation capacity to reach approximately 278 GW by 2030, close to the 292 GW target, and increase to around 1,370 GW by 2047–slightly below NITI Aayog’s projected current-policy range of 1,430–1,650 GW by 2050.
The Vision 2047 pathway factors in additional electricity demand from emerging industries and infrastructure. Assuming the full implementation of planned programmes, ISMA estimates that India’s installed solar capacity could reach 313 GW by 2030 and approximately 2,275 GW by 2047, enough to meet nearly half of the country’s electricity demand.
To support this expansion, India’s solar PV manufacturing industry is projected to achieve cumulative capacities of approximately 3,484 GW for modules, 3,128 GW for cells, 2,630 GW for ingots and wafers, and 2,200 GW-equivalent for polysilicon by 2047.
Manufacturing capacity across the value chain is expected to scale up rapidly, supported by government-backed projects mandating the procurement of domestically manufactured solar products.
The expansion could create a significant employment opportunity, with total manufacturing-related jobs rising from approximately 4.1 lakh currently to about 7.4 lakh by 2030 and 32.3 lakh by 2047. Direct employment within solar PV manufacturing plants could increase from around 1.4 lakh to 11.1 lakh.
The share of direct jobs in cells, wafers and polysilicon rises from about one in ten today to about a third by 2030 and more than half by 2047. These are skilled jobs for technicians, engineers and chemists. 
The report estimates that approximately $89 billion in new solar PV manufacturing investments could be required by 2047 under the Vision pathway, translating into an average investment requirement of around $4.3 billion annually between 2027 and 2047. Nearly 70% of these investments are expected to flow into polysilicon, wafers and cells. The Production Linked Incentive (PLI) scheme has already attracted approximately $8.4 billion in investments by June 2026, with every dollar of incentive drawing around four dollars in private investment.
A deeper domestic manufacturing ecosystem could also substantially reduce India’s dependence on imported solar components. The report projects that the country’s annual solar import bill could decline from approximately USD 4.4 billion currently to zero by 2041 under the Vision 2047 pathway. India could further account for 26.5% of global solar module supply by 2047, compared with around 5.9% under the current policy scenario by 2030.
Amit Manohar, Secretary General, ISMA, said, “India’s solar manufacturing sector stands at a pivotal moment, with the Vision 2047 pathway presenting an unprecedented opportunity to build a globally competitive, integrated manufacturing ecosystem. The potential to attract USD 89 billion in investments, generate over 32 lakh jobs and significantly reduce import dependence underscores the strategic importance of strengthening domestic manufacturing across the entire solar value chain. Realising this ambition will require sustained policy support, a predictable demand pipeline, investments in upstream manufacturing and continued efforts to strengthen India’s global competitiveness.”
The report identifies policy certainty, sustained domestic demand and timely implementation of manufacturing programmes as critical to realising this ambition. It calls for maintaining firm timelines under the Approved List of Models and Manufacturers (ALMM), completing PLI-supported projects, expanding rooftop solar and agricultural solarisation programmes, and accelerating investments in upstream manufacturing. It also highlights the need to develop domestic manufacturing equipment, strengthen technical skills, promote advanced cell technologies, establish recycling frameworks and expand export markets.
The Vision 2047 pathway outlines a phased transition, with cells scaling up through 2030, wafer manufacturing expanding through 2035 and the complete solar manufacturing value chain becoming established thereafter.
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The new issue of pv magazine Global is out now!
Available in print and digital – get your copy today!
Friday, November 13, 2026
10:00 am – 11:00 am CET, Berlin, Paris, Madrid
Monday, November 23, 2026
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Japanese solar project developer Sun Village has announced the grid connection of a solar-plus-storage facility with a DC/AC oversizing ratio of 327% at an undisclosed location in Japan.
Described by the company as a “low-voltage, super-oversized” solar power plant with battery storage, the facility features 163.2 kW of installed PV capacity, a 253.3 kWh battery storage system and a 49.9 kW power conversion system (PCS).
In Japan, low-voltage solar projects typically have an AC output of less than 50 kW, while super-oversizing refers to installing PV capacity substantially above the rated output of the PCS. This configuration allows developers to increase electricity generation without expanding grid connection capacity.
Super-oversizing differs from conventional oversizing in its significantly higher ratio of installed PV capacity to inverter output, often exceeding 300%. By comparison, the average oversizing ratio for solar installations with capacities between 10 kW and 50 kW commissioned in Japan in 2024 was approximately 180.5%, according to the Ministry of Economy, Trade and Industry (METI).
“The plant is expected to sell approximately 222,000 kWh of electricity annually,” Sun Village said in a statement. “The DC-coupled configuration allows surplus electricity that would otherwise be curtailed during peak daytime production to be stored in the batteries and sold in the evening and at night, when solar generation declines.”
According to the company’s simulations, the system is expected to maintain a stable electricity output of 49.9 kW for approximately 14 hours. Under Japan’s feed-in premium (FIP) scheme, Sun Village will act as an aggregator, handling generation forecasts, power generation planning and battery operations, while selling electricity on the wholesale electricity market.
Such configurations could gain traction in Japan as developers seek to maximize generation from existing grid connections amid constraints on available grid capacity and rising interconnection costs. Combining heavily oversized PV arrays with battery storage could allow operators to capture electricity that would otherwise be lost through inverter clipping, while extending electricity exports beyond daylight hours.
Japan’s gradual shift from fixed feed-in tariffs to market-linked remuneration under the FIP scheme could also support wider adoption of solar-plus-storage projects. By storing electricity during periods of high solar output and selling it when wholesale prices are higher, developers could improve project revenues and reduce exposure to low midday electricity prices. However, the economic viability of super-oversized systems will depend on battery costs, electricity price spreads and the amount of otherwise curtailed generation that can be recovered.

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The new issue of pv magazine Global is out now!
Available in print and digital – get your copy today!
Day 1 | Europe’s Solar and Storage Markets 2027: What works where?
Day 2 | Solar + Storage Co-location: Three markets, three business cases
Day 3 | Solar Quality: Which technical risks still need better answers?
Day 4 | Cybersecurity and Procurement: What can European solar projects source in 2027 and beyond?
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New Delhi, Nov 4 (IANS) India is rapidly strengthening its position in global renewable energy markets, with the country’s expanding clean energy capacity enhancing energy security, reducing dependence on imported fuels and creating new manufacturing opportunities, according to a new report released by the International Energy Agency (IEA).
Launched at the Bharat Renewable Energy Summit in the national capital, the India Renewable Energy Market Report 2026 said the country’s renewable power capacity has nearly quadrupled over the past decade, crossing 300 gigawatts (GW) in 2026.
India is now the world’s second-fastest-growing renewable energy market and the second-largest manufacturer of solar photovoltaic (PV) modules.
The report noted that India achieved its target of sourcing 50 per cent of installed power capacity from non-fossil fuel sources in 2025, five years ahead of schedule, underscoring the pace of its clean energy transition.
According to the IEA, the rapid deployment of renewable electricity has already delivered significant economic and energy security benefits. Renewable power generation helped India save more than $100 billion in coal and natural gas import costs between 2011 and 2025. These cumulative savings are expected to more than double by the end of the decade.
The agency estimated that without the solar, wind and bioenergy capacity added since 2010, India’s coal imports in 2025 would have been around 110 million tonnes higher.
Looking ahead, the report forecasts India’s renewable energy capacity to reach around 530 GW by 2030, with solar PV accounting for more than 80 per cent of all new installations.
The growth trajectory is expected to keep the country on track to meet its broader non-fossil power capacity goals.
IEA Executive Director Fatih Birol said India’s renewable energy expansion is delivering major energy security benefits at a time of heightened uncertainty in global energy markets.
He noted that India’s experience demonstrates how stable and consistent policy measures can help lower renewable energy costs, attract investments and provide lessons for other emerging economies.
Union Minister for New and Renewable Energy Pralhad Joshi said India’s rise as a major renewable energy player reflects the progress made in recent years.
–IANS
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By Canary Media
Canary Media
4 November 2026
It’s cranberry season in southeastern Massachusetts. At bogs throughout the region, growers are collecting the ruby-red berries destined for holiday cakes, juice bottles, and cans of jellied sauce. At two farms, however, the harvesting process looks a little different: Pickers are navigating equipment around metal poles in the shade of solar panels. 
The two bogs are the first in the country — perhaps the world — to grow cranberries beneath an operating solar installation. This fall marks the second season cranberries have been harvested from beneath the panels.
“We are literally proving it can be done,” said Prateek Tare, co-founder and executive vice president of Distributed Energy Infrastructure. His company constructed the two projects — a 4.4-megawatt array paired with a 13.5-megawatt-hour battery in the town of Kingston, and a 1-MW solar array in neighboring Plymouth. 
Solar development is a major part of Massachusetts’ plan to reach net-zero carbon emissions by 2050. The state has offered solar incentives since 2001, evolving and expanding them over the decades to drive even more development. 
However, the question of where to site solar projects has become a major point of contention in the densely populated and heavily wooded state. Building on rooftops and parking lots in developed areas can increase costs and limit generation capacity. But proposals for arrays on previously undeveloped land often spark protests from locals worried about the character of their community and environmental groups opposed to disrupting ecosystems. Using pre-cleared farmland has potential, but raises concerns about taking agricultural acres out of production. Many of these same dynamics are at play in communities across the U.S.
One of the solutions Massachusetts has been encouraging is agrivoltaics, or dual-use solar, which involves building solar panels above active agricultural operations. This strategy, which is gaining traction nationwide, allows farmland to be used for energy generation even as livestock graze or crops flourish beneath the elevated arrays. 
In 2018, Massachusetts became the first state to offer a financial boost to dual-use solar projects like these. The state’s solar incentive program pays participants a set rate for every kilowatt-hour of electricity they generate; an array with a capacity between 1 MW and 5 MW currently gets a base rate of 23.17 cents. Agrivoltaic projects get an extra 9 cents per kilowatt-hour. 
That can be enough money to attract developers interested in leasing land for solar arrays or, less commonly, buying property outright with an agreement to keep it in agricultural use. Farmers who agree to lease are also generally paid for their services maintaining the landscape around the panels and poles. 
In Kingston and Plymouth, clean energy developer Greenbacker Renewables bought the land, which had been home to cranberry-growing operations for decades, from farmers who were ready to get out of the business. Greenbacker then worked with Distributed Energy Infrastructure to build the arrays, and hired Iain Ward, a solar consultant and longtime cranberry farmer in the area, to manage the growing operations. Both projects use a community solar model, selling power to customers interested in the lower prices and environmental benefits offered by renewable energy.
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Solar can be particularly advantageous for cranberry farmers in Massachusetts, which grows more of the fruit than any state other than Wisconsin. While sheep farms and cornfields can often be sold to housing or commercial developers, cranberry bogs are protected wetlands: Even if they go out of production, they cannot be built on. Not all bogs are well placed to connect to the grid, but for those that are, solar panels can be a financial lifeline. 
“This is a farm viability opportunity,” Ward said. 
Figuring out how to build a solar array over a cranberry bog was a unique puzzle, Tare said. The first challenge was the foundations. For most solar arrays, the foundation goes 8 to 10 feet into the ground, he said. But in a cranberry bog, you have to go well past that to find ground solid and stable enough to hold the pilings. It took some trial and error to find the right machine to sink piles that deep. Wiring couldn’t be buried in the boggy ground, so it had to be hung overhead. 
“You’re trying to figure it out from a farmer’s perspective,” said Tare, who worked closely with Ward on the design of the two projects. 
The resulting installations have photovoltaic panels mounted 10 feet off the ground on an axis that allows them to tilt throughout the day to follow the sun. Pilings are spread farther from each other than standard so that harvesting equipment can be moved freely through the bog. 
These successes in Kingston and Plymouth have led to more agrivoltaic opportunities for Tare’s company, including arrays in apple orchards, a cattle pasture, and a Christmas tree farm. Preliminary work is also underway at another bog. 
Meanwhile, a stalled cranberry solar project in the nearby town of Carver could be resuscitated. Five years ago, a different pair of bogs there were set to become the nation’s first cranberry agrivoltaic operations. The arrays were built, and crops are growing beneath them, but the company behind the developments went bankrupt before they could get up and running. Today, the new bog owner has ​“every intention to finish them,” Ward said. 
“They’re not a failure,” Ward said. ​“There is an opportunity for them to be finished.”
Tare expects future cranberry projects to get easier each time, as the company carries forward the lessons it learns. Though momentum has been slow so far, Ward expects development to accelerate soon. 
“It is picking up steam, and the lessons learned have been significant, he said. ​“When you change a paradigm it takes a little time.”
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Sarah Shemkus is a reporter at Canary Media who is based in Gloucester, Massachusetts, and covers New England.
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USD 1.7
Baku 13 °C
USD 1.7
Baku 13 °C
Work on the installation of photovoltaic modules has been 50% completed as part of the construction project of the Shafag solar power plant (SPP) located in Azerbaijan's Jabrayil district, APA-Economics reports, citing bp's report on the results of its operations in Azerbaijan for the first nine months of 2026.
"In the third quarter of 2026, construction work on the Shafag solar project progressed at the project site located in Jabrayil district. The procurement and delivery of major equipment, including photovoltaic modules and structural components, were successfully completed, and significant progress was achieved in the installation of piles and tracker systems. Electrical installation activities also commenced and continued according to plan during the quarter. By the end of the third quarter, module installation work was 50% complete," the report stated.
The project has also continued to demonstrate strong occupational safety performance, with a total of 1 million working hours completed without any recordable injuries.
The use of local resources in the project's construction work continues to increase. Currently, 444 local workers are involved in the project, including 150 newly resettled residents of the territories liberated from occupation. More than 700 jobs are expected to be created during the peak construction period, and the existing accommodation blocks at the site are currently being expanded to accommodate the growing workforce.
Construction work on the project is planned to continue until mid-2027.
The shareholdings in Shafag Jabrayil Solar Limited (SJSL) are as follows: bp (40.01%), SOCAR Green (39.99%), Azerbaijan Business Development Fund (10%), and MVM (10%).
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A solar and battery system at the Experimental Lakes Area east of Kenora could save about 80,000 litres of diesel a year, leaving more money available for freshwater research and maintenance at the remote field station.
The roughly $2-million project recently earned IISD Experimental Lakes Area the Canadian Renewable Energy Association’s Canadian On-Site (BTM) Project of the Year award. The association presented the honour Oct. 19 at its annual gala in Toronto.
For operations manager Roger Mollot, the project addresses a challenge the off-grid facility has faced since it opened in 1968: generating electricity for its laboratories, residences, commercial kitchen and dining hall.
“So, we’ve been relying on diesel generators for almost six decades,” he said.
Planning began about 10 years ago, driven by a desire to reduce the station’s diesel consumption and carbon emissions. That work included an engineering study to design a system combining solar power, battery storage and diesel generators.
Upgrades began in 2025, with all components in place by the end of that year. Testing and commissioning have continued through 2026.
The installation includes 297 kilowatts of solar generating capacity, a 250-kilowatt inverter and battery storage. It is expected to replace up to 80% of the station’s diesel-generated electricity, although that target has yet to be confirmed over a full year.
Summer observations have been encouraging. Mollot said solar power and stored battery energy supplied the facility’s electricity for about 20 hours a day, with diesel generators running for the remaining four hours.
When sunlight is sufficient, the panels power the station and charge the batteries. After sunset, the batteries take over. If their charge falls to a set threshold, the generators start automatically to supply electricity and recharge them.
With shorter days approaching, Mollot expects the generators to run longer during winter.
Staff are continuing to monitor performance and troubleshoot the system alongside electrical contractors and engineers, who can also monitor the powerhouse remotely.
Mollot said achieving the projected reduction would save about 80,000 litres of diesel annually. Rising diesel prices have made fuel an increasingly significant part of the station’s operating budget.
Reducing that expense would allow the organization to direct more money toward science programming and maintenance, he said.
The facility studies human impacts on freshwater ecosystems through whole-lake experiments. Researchers introduce and study environmental stresses at the whole-lake scale, helping them understand changes affecting lakes and rivers elsewhere.
Environment and Climate Change Canada helped finance the energy project, alongside donations from individuals and private foundations.
Dryden-based KPE Electrical Contractors and Charge Solar helped design and install the system. Mollot said the national recognition is shared with those partners.
While installing renewable energy at a remote station required planning, Mollot said the main hurdle was financial.
“I really feel that the barrier here is putting the financing in place,” he said.
Over the past decade, he said, technology has become more affordable. Remote monitoring also means facilities can draw on engineering expertise without having those specialists permanently on site.
“That engineering capacity can be sitting anywhere in the world,” Mollot said.
He believes the combination of government funding and private contributions that supported the project could help other remote facilities reduce their reliance on diesel.
The award’s behind-the-meter category recognizes on-site energy projects. At Experimental Lakes Area, all the renewable electricity generated is used by the facility itself.
A member of the organization’s communications staff attended the gala in Toronto.
Mollot said the honour stands apart from the recognition Experimental Lakes Area usually receives for its science. This time, it is the work of powering that research and reducing the station’s own emissions that has drawn national attention.
— Pam Fedack is a Local Journalism Initiative reporter who works out of the Kenora Miner and News. The Local Journalism Initiative is funded by the Government of Canada.
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India’s renewable energy challenge is moving beyond the question of how much solar and wind capacity can be installed. The harder test is whether clean electricity can be made dependable, stored, financed and delivered at the scale required by homes, businesses and public infrastructure. That is the central argument advanced by Vineet Mittal, chairman of Avaada Group, in an interview linked to the Bharat Renewable Energy Summit & Expo 2026.
Mittal’s assessment places the next phase of India’s energy transition at the intersection of generation, manufacturing, storage and grid management. His argument is that India has already shown it can produce solar electricity at globally competitive prices, but must now build the technological and institutional capability to make renewable power available around the clock and remain globally competitive.
The distinction matters because renewable generation and dependable electricity are not the same thing. Solar output varies by time of day, while wind generation depends on weather conditions. A system that relies on these sources therefore requires storage, flexible power management, transmission capacity and financing structures that can support projects over long operating periods. The interview does not provide national capacity or reliability figures, but it identifies the components that industry believes must be developed together.
The Bharat Renewable Energy Summit and Expo is presented by Mittal as more than a conference platform. In his view, such events can connect three requirements of the transition: investment to create scale, innovation to make renewable energy dependable, and international cooperation to extend access. These are not separate challenges. A factory without buyers, a generation project without transmission, or a storage system without a workable financing and regulatory framework cannot by itself create a reliable clean-energy system.
The emphasis on manufacturing also reflects a shift in how India’s renewable ambition is being framed. Mittal argues that installing solar panels is different from mastering the technologies behind them. He identifies a broad value chain that includes polysilicon, ingots, wafers, high-efficiency cells, modules, glass, batteries, power electronics and intelligent energy-management systems. The list points to the industrial depth required if India wants to reduce dependence on imported components and capture more value from the energy transition.
However, the interview itself does not establish how much of this value chain is currently available in India, what capacity is operational, or how domestic products compare with international alternatives on cost and efficiency. Those questions remain important for assessing whether manufacturing ambitions are translating into competitive industrial capability. Mittal’s position is that leadership should be measured not only by production volume, but also by efficiency, reliability, cost and continuing innovation.
Avaada’s own stated strategy illustrates this integrated approach. Mittal refers to the company’s investments in advanced TOPCon solar cells, integrated solar manufacturing, battery storage and green fuels. He also mentions the company’s HALO integrated battery and hybrid inverter solution. These references are corporate claims and product descriptions from the interview; the supplied material does not provide independent technical performance data, deployment numbers or project outcomes. Their significance lies in the business model being proposed: connecting electricity generation with manufacturing and energy-management systems rather than treating solar generation as a standalone activity.
Storage is central to that model. For households, batteries can potentially shift daytime solar generation into evening consumption. At a wider system level, storage can help manage variable generation and reduce pressure on the grid during periods when renewable output falls. But storage also introduces costs, replacement requirements, financing needs and operational questions. The interview identifies the need for batteries and intelligent inverters but does not quantify the investment required or specify the regulatory arrangements that would allow distributed systems to support the grid.
This is where programmes such as PM-KUSUM and PM Surya Ghar enter the discussion. Mittal describes them as examples of public policy making ordinary citizens participants in the energy economy. The programmes are used in the interview as a framework for considering how households and farmers might become producers, consumers and, where regulations and infrastructure permit, contributors to virtual power plants.
The proposition is significant for urban and rural infrastructure alike. Rooftop solar combined with storage could change the relationship between households and electricity networks by allowing some consumption to be supplied locally and shifted over time. Yet the feasibility of virtual power plants depends on technical standards, metering, communication systems, distribution-company arrangements and rules governing power exported to the grid. The interview explicitly qualifies this possibility by referring to regulatory and infrastructure conditions. It does not claim that such systems are already operating at national scale.
The citizen-facing test is therefore not simply whether panels can be installed. It is whether households receive affordable electricity, reliable supply, simple financing and dependable maintenance. These are practical conditions that determine whether a clean-energy programme becomes useful infrastructure or remains an equipment-distribution exercise. A rooftop system that is difficult to finance, poorly maintained or unable to work during outages may not deliver the benefits expected from its installed capacity.
Mittal makes a similar argument for developing countries through the International Solar Alliance. He calls for complete solutions combining generation, storage, financing, local entrepreneurship and long-term maintenance. The underlying point is that technology must be adapted to local economic and infrastructure conditions. Equipment designed for a wealthier or more technically mature market may not be suitable where financing is limited, maintenance networks are weak or electricity systems are less reliable.
For India, this international dimension also creates an opportunity to export systems and implementation experience rather than only hardware. The interview argues that developing countries need solutions that are affordable, durable, easy to maintain and suited to local requirements. It does not provide details of specific international projects or financing arrangements, so the extent of India’s existing role in delivering such integrated systems cannot be established from the supplied material.
Financing is the other major constraint identified in the interview. Mittal says India does not lack clean-energy opportunities; the challenge is converting them into bankable projects at the required speed. He points to sovereign wealth funds, pension funds, development finance institutions and global technology companies as potential partners. The emphasis on predictability is important because renewable-energy projects require substantial upfront capital and depend on revenue stability over long periods.
The difference between an announcement and an operating asset is particularly important in infrastructure. Mittal argues that investment commitments should ultimately become factories, transmission lines, operating projects and affordable electricity. This provides a useful measure for assessing the practical outcome of summit-led investment discussions. Announced capital may indicate interest, but it does not by itself demonstrate land acquisition, approvals, procurement, construction, grid connection or commercial operation.
That implementation chain also reveals the institutional nature of the reliability challenge. Renewable energy is often discussed as a generation problem, but dependable supply requires coordination among manufacturers, project developers, lenders, distribution companies, transmission operators, regulators and consumers. Public policy can create demand and reduce barriers, while private companies can provide capital and technology. Neither side can deliver a complete system without the other.
The evidence supplied in the interview supports a clear conclusion: India’s clean-energy transition is entering a more complex phase. The focus is shifting from adding generation capacity to building an ecosystem that combines domestic technology, storage, intelligent management, accessible finance and dependable service. The source provides a corporate perspective on that transition rather than an independent assessment of national progress. It therefore confirms the priorities being articulated by industry, but not whether the required transformation has been achieved.
The developments to monitor are concrete. They include whether summit commitments become operating projects, whether manufacturing expands across the value chain, whether storage becomes affordable and reliable, and whether programmes such as PM-KUSUM and PM Surya Ghar can support sustained household and community participation. India’s next clean-energy test will be measured not only in installed capacity, but in the reliability and affordability of the electricity that reaches people when they need it.

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The usual answer to surplus rooftop PV in a British home has been an immersion diverter. A current clamp on the meter tails detects export, and the diverter feeds that spare power into the immersion element in the hot water cylinder, varying the power to match whatever is spare. The kit is cheap, it works with almost any cylinder, and it suited homes heated by gas, where the cylinder’s hot water would otherwise have come from the boiler.
Homes in England and Wales are replacing gas boilers with air-to-water heat pumps under the Boiler Upgrade Scheme, and some of them already have panels on the roof or add them at the same time. In those homes the diverter’s arithmetic stops working the way it used to.
An immersion element is a resistance heater. One kWh of electricity in gives one kWh of heat in the water. A heat pump moves heat from outside air into the water, so the same kWh of electricity delivers several kWh of heat.
The government’s Electrification of Heat demonstration project ran one of the largest UK field trials of heat pump performance. Its interim analysis by Energy Systems Catapult measured a median seasonal performance factor of 2.80 across 291 air source heat pumps, using a boundary that counts space heating, hot water, back-up heaters and immersion use together. The report notes that summer hot water runs are less efficient than the annual picture, because the heat pump runs less often and works against a higher target temperature.
The comparison does not need a precise summer figure. A heat pump in hot water mode beats the immersion for every kWh of surplus as long as it delivers more than one kWh of heat per kWh of electricity, and a working air-to-water unit clears that bar by a wide margin.
The value of a kWh of surplus PV depends on what it displaces. Take the Ofgem price cap for October to December 2026, 26.32 p per kWh of electricity for a direct debit customer, and the EoH median of 2.80 p.
In a heat pump home, the heat pump would otherwise make the cylinder’s hot water from grid power at about 9.4 p per kWh of heat. A kWh of surplus sent through a diverter into the immersion makes one kWh of heat, so it saves about 9.4 p. If the heat pump itself runs on that same kWh of surplus, the electricity it would have bought from the grid comes off the roof instead, and the saving is the full 26.32 p. On these figures, pointing surplus at the heat pump is worth close to three times as much as pointing it at the immersion.
The same arithmetic changes how the diverter compares with export. Under the Smart Export Guarantee, each supplier sets its own export rate, and Ofgem requires only that it stays above zero. In a gas-heated home the diverter competed against the gas price. In a heat pump home it competes against 9.4 p, so a household on an export tariff paying more than that would do better selling the power than heating water with the element.
Time-of-use tariffs move the numbers. A household that heats its cylinder overnight on a cheap rate pays far less than the cap for that heat, which shrinks the value of any daytime surplus spent on hot water. The tariff should be chosen before the controls are set. “Somebody on a cheap overnight rate and a good export rate may be better off exporting at midday and heating water at 2am. Somebody on a flat rate should run the cylinder in the solar window. You cannot set the controls without knowing the tariff,” reads Eco Renewables’ guide to time-of-use tariffs for heat pump homes.
The diverter keeps one practical advantage. It can use any surplus, however small, because it can run the element at any power level. A heat pump compressor has a minimum power draw and works best on longer runs, so it needs a steady surplus through a stretch of the day. A British June afternoon with broken cloud gives a diverter something to use and may give a heat pump controller nothing it can act on.
The cylinder also limits the gain. Lifting 200 litres of water by 10 C stores about 2.3 kWh of heat. A heat pump at an efficiency of 2.8 needs about 0.8 kWh of electricity to do it, where an immersion needs the full 2.3 kWh. The heat pump fills the same tank from a third of the surplus, which leaves the rest of the afternoon’s generation for a battery or for export.
The immersion has a second job in a heat pump home: a periodic pasteurisation cycle. HSE guidance on legionella says hot water should be stored at 60 C or above to kill the bacteria, a temperature that costs some heat pumps more electricity to reach than their normal hot water setpoint. Scheduling that cycle in the middle of a sunny day lets the PV pay for it, and it gives the diverter a role in a heat pump home without competing with the compressor.
The control link is the harder part. Germany’s heat pump association BWP runs the SG Ready label, which defines the operating states a heat pump controller must accept from outside. In state 3 the heat pump runs in boosted mode and raises the setpoint in the buffer or hot water store to soak up surplus electricity. State 4 is a definite start command. An inverter, energy manager or battery system with a free contact can signal the heat pump when export passes a threshold the installer sets.
The decision about priority belongs at the design stage. “We work out which load takes the surplus first: the battery, the cylinder through the heat pump, or the immersion. If the battery fills by lunchtime in summer, the heat pump should get the next kilowatt-hour, and the immersion only the scraps,” reads Eco Renewables’ guide to running a heat pump alongside rooftop solar and its explainer on how a heat pump heats a hot water cylinder covers cylinder sizing and reheat times.
The seasons limit all of this. The surplus is largest in summer, when the heat pump’s only load is hot water, and smallest in December, when space heating demand peaks and a south-facing array in Berkshire produces a fraction of its June output. Hot water is the one heat load that runs all year, which is why it is the natural first home for spare PV.
Installing heat pumps, solar panels and batteries in homes in Great Britain carries 0% VAT until 31 March 2027 under HMRC notice 708/6, rising to 5% from 1 April 2027. The 28 October Budget confirmed that date and added heat batteries, the phase-change stores sold as compact cylinder replacements, to the energy-saving materials list at 5% from the same day. A heat battery charged by its own electric element sits on the immersion side of the arithmetic above, so a home choosing one over a cylinder gives up the heat pump’s multiplier on that store.
Author: Adam Dare
Adam Dare is Managing Director of Eco Renewables, an MCS certified installer of heat pumps, solar panels and home batteries in Binfield, Berkshire. He is Heat Geek trained and verified, with a Gas Safe background.

The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine.
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Day 3 | Solar Quality: Which technical risks still need better answers?
Day 4 | Cybersecurity and Procurement: What can European solar projects source in 2027 and beyond?
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The facility will produce 3GW of PV cells annually, boosting US solar supply chain transparency, resilience.
Inox Solar Americas has confirmed that its planned photovoltaic (PV) cell manufacturing facility in Greenville, North Carolina, is on track to begin production in the second quarter (Q2) of 2027.
The US-based company states that the new plant will have an annual capacity of 3GW and occupy 515,460ft².
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The facility forms a core element of Inox Solar Americas’ efforts to develop a vertically integrated domestic solar manufacturing platform within the US.
According to the company, producing PV cells domestically will complement its current US-based PV module output, increasing access for customers to solar technology made in the country and expanding the transparency and resilience of the domestic supply chain.
Inox Solar Americas’ manufacturing strategy emphasises domestic content across its products. The company says this will help customers address shifting requirements related to domestic content, “Foreign Entity of Concern” and “Prohibited Foreign Entity” considerations, relevant trade regulations, and provisions stemming from federal energy policy.
The company is focused on documented manufacturing procedures, qualified sourcing, and compliance readiness intended to assist customers managing complex procurement and project planning.
Integrating PV cell and PV module production in the US is also expected to help improve visibility and control throughout the solar supply chain.
The company indicates it is strengthening processes for supplier qualification, sourcing documentation, traceability of materials, and due diligence, to offer customers clearer insight into the origins and manufacturing details of their products.
Increasing domestic production is also intended to reduce reliance on imported PV cells and limit exposure to global supply disruptions or trade-related risks.
The Greenville facility will feature the company’s Galaxion monocrystalline PV cell technology, alongside its Gamma Series monofacial and Vega Series bifacial PV modules.
Inox Solar Americas reports that the plant will use automated manufacturing systems and process controls to maintain consistent quality and production traceability from PV cell fabrication through to finished modules.
Inox Solar Americas president and CEO Ashok Nair said: “By bringing advanced cell technology, high-performance module manufacturing, and rigorous quality control together within our US manufacturing platform, we are strengthening our ability to support customers with reliable supply and the bankability required for their project pipelines.”
In September 2026, Inox Solar Americas secured a deal to supply 767MW of PV modules to a US-based renewable energy developer and independent power producer (IPP).
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Hybrid power plants pairing wind and solar power with a battery can supply up to 90% of Kazakhstan’s typical demand profile for a delivered cost below $60/MWh, according to the latest report from energy think tank Ember.
Ember’s report says Kazakhstan needs “new power capacity quickly”, with its electricity demand rising 16% in the last five years. Coal still dominates Kazakhstan’s electricity mix, supplying 62% of electricity generation in 2025, but its coal units are on average over 50 years old, leading to frequent equipment failures. Ember says there were 891 incidents of various severity between January and July this year.
“To replace its ageing infrastructure and keep pace with fast-growing demand, Kazakhstan needs to build more capacity quickly and ensure its availability during peak periods, including winter demand spikes,” Ember’s report says. “The capacity also needs to be built close to where demand is to relieve pressure on the transmission network.”
Ember’s research analysed 15 sites, chosen for their proximity to a major demand centre and an existing power line, across all three of Kazakhstan’s power zones. It tested 125 combinations of wind, solar and battery capacity at each site, producing 1,875 simulations. Each configuration was simulated hour by hour over a 30-year project life using site a typical hourly demand profile that represented national demand patterns and was scaled to a peak of 100 MW.
Results found the best-performing configurations at each site could supply between 70% and 90% of the electricity in a typical demand profile, hour by hour, over 30 years, at a delivered cost below $60/MWh.
“This cost represents the plant’s lifetime cost per MWh actually delivered, including the cost of curtailed output,” Ember’s report says. Across all 15 sites, the average delivered electricity cost is $56/MWh. Ember says this is significantly cheaper compared to new coal, which costs $70-170/MWh, depending on the region and technology.
Kostantsa Rangelova, Senior Battery Analyst at Ember, told pv magazine that while there is real potential for solar-plus-battery projects in Kazakhstan, the potential is even greater when wind is added.
“Solar is really cheap and very fast to build here,” Rangelova said. “Shifting some of it to the evening with a battery unlocks its full value, making its potential contribution to electricity supply larger than with standalone solar.”
Rangelova added that the challenge for solar lies in the Kazakh winter, which often brings cloudy days that mean solar-plus-storage produces less when demand is highest. 
“Solar-battery projects do not need wind to be viable, but on their own they are a summer-heavy source of power,” she continued. 
“Kazakhstan’s advantage is its vast untapped wind, which is strongest in exactly those winter months. Combining wind and solar behind one grid connection, overbuilding generation capacity and accepting some curtailment by design means only a small battery is needed to reach a high capacity factor at low cost.”
Ember’s hybrid simulations feature curtailment by design in order to minimise the battery need and make it possible to meet over 70% of winter demand at most sites. The report explains that deliberately oversizing the generation means there is enough generation even on less windy and sunny days when paired with a small battery.
This offers a capacity factor comparable to that of a baseload power station, it continues, but at a lower cost than new coal.
Rangelova also told pv magazine the report findings can be very relevant for renewable energy procurement schemes, explaining that while hybrid plants provide flexibility for the power service, their service needs to be rewarded and priced into procurement costs. 
“An auction that asks for a specific supply profile and lets bidders find the lowest-cost mix of wind, solar and battery to meet that profile would price that flexibility in and lower system costs,” she suggested.
Rangelova also recommended batteries have access to balancing, reserve and capacity revenues in order to provide the best value for the investment made in them. 
“Batteries co-located with renewables under a mandate that only shift their own plant’s output remain underused and never deliver their full value to the system,” she said. “It is like owning a Swiss Army knife and only ever using the blade.”
Figures released by Kazakhstan’s Ministry of Energy in April put the country’s cumulative renewables capacity at 3.7 GW, including 1.37 GW of solar. At the time, the ministry said it planned to commission 245 MW of renewables this year, including five solar projects with a combined capacity of 92.6 MW.
Additional figures from Ember’s report says wind and solar could supply 23% of Kazakhstan’s electricity generation by 2035, up from 6% in 2025, bringing total renewables generation to 35%.
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Day 1 | Europe’s Solar and Storage Markets 2027: What works where?
Day 2 | Solar + Storage Co-location: Three markets, three business cases
Day 3 | Solar Quality: Which technical risks still need better answers?
Day 4 | Cybersecurity and Procurement: What can European solar projects source in 2027 and beyond?
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Shenzhen Nanshan Power, a Chinese power producer backed by state-owned capital, plans to acquire a controlling stake in Trina Solar’s tracker business.
According to an Oct. 30 announcement, Shenzhen Nanshan Power signed a preliminary equity acquisition agreement with Trina Solar and its wholly owned subsidiary, Trina Solar (Changzhou) Science & Technology.
Under the proposed transaction, Shenzhen Nanshan Power would acquire a 51% to 70% stake in the Changzhou-based company operating TrinaTracker, Trina Solar’s solar tracking unit.
The target company, established in February 2019, is currently wholly owned by Trina Solar through its Changzhou subsidiary. If completed, the acquisition would give Shenzhen Nanshan Power control of the business and allow it to consolidate the subsidiary’s financial results.
The acquisition would be financed entirely in cash and is expected to qualify as a major asset restructuring under Chinese securities regulations. It would not involve the issuance of new shares or a change in Shenzhen Nanshan Power’s controlling shareholder.
The companies have yet to agree on the final equity stake, valuation or payment schedule. The purchase price will be determined following an independent asset valuation, while performance commitments and compensation arrangements are expected to be negotiated as part of a definitive agreement.
TrinaTracker supplies solar tracking systems, including its Vanguard-1P and Vanguard-2P products, alongside intelligent control technologies. According to Trina Solar, the business had delivered more than 43 GW of tracking systems across more than 70 countries by the end of 2025, with annual global production capacity exceeding 15 GW.
Wood Mackenzie ranked TrinaTracker second in its 2026 global tracker manufacturer assessment, which evaluates companies based on service capabilities, research and development, supply chain resilience and financial strength, rather than shipment volumes alone.
In comments to Chinese media on Nov. 2, Trina Solar said it intended to introduce a strategic partner to strengthen operational synergies. The company said it would continue to focus on its solar and energy storage businesses while developing integrated energy solutions and technologies for AI data centers.
The proposed sale comes amid continued financial pressure on China’s solar manufacturing sector. Trina Solar reported a net loss attributable to shareholders of CNY 1.94 billion ($285 million) for the first nine months of 2026, on revenue of CNY 47.98 billion.
Selling a majority stake in the tracker subsidiary could provide Trina Solar with additional capital while allowing it to retain a minority interest. The arrangement could also preserve opportunities for cooperation between its module and tracking systems businesses, although the companies have not disclosed any post-transaction supply or cooperation agreements.
The proposed deal reflects a broader push among Chinese renewable energy companies to explore ownership restructuring and strategic partnerships as they seek to balance investment requirements with business specialization amid intense competition.
Both companies stressed that negotiations remain at a preliminary stage. Due diligence, financial audits, asset valuation and corporate approvals must be completed before a binding agreement can be signed.
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The new issue of pv magazine Global is out now!
Available in print and digital – get your copy today!
Day 1 | Europe’s Solar and Storage Markets 2027: What works where?
Day 2 | Solar + Storage Co-location: Three markets, three business cases
Day 3 | Solar Quality: Which technical risks still need better answers?
Day 4 | Cybersecurity and Procurement: What can European solar projects source in 2027 and beyond?
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As a media partner of Genera 2026, pv magazine will organize and moderate a session in Spanish in Madrid, during International Electrification and Decarbonization Week.
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India’s solar manufacturing industry could become a fully integrated global powerhouse by 2047, creating 3.23 million direct and indirect jobs, attracting $89 billion in manufacturing investment, and eliminating the country’s solar import bill, according to a report by the Indian Solar Manufacturers Association (ISMA).
The report outlines a roadmap for India to move beyond module assembly and develop domestic manufacturing capabilities across the solar value chain, from polysilicon and ingots to wafers, cells, and modules. The transition could enable India to capture a significantly larger share of the value generated by domestically manufactured solar panels while strengthening its position in global markets.
Under a current-policy scenario, ISMA projects India’s installed solar capacity to reach approximately 278 GW by 2030, approaching the 292 GW target, before rising to around 1,370 GW by 2047. The latter figure is slightly below NITI Aayog’s current-policy projection of 1,430 GW to 1,650 GW by 2050.
The Vision 2047 scenario accounts for additional electricity demand from emerging industries and infrastructure. Assuming full implementation of planned programs, ISMA estimates that India’s installed solar capacity could reach 313 GW by 2030 and approximately 2,275 GW by 2047, enough to meet nearly half of the country’s electricity demand.
To support this expansion, India’s solar PV manufacturing industry would need to achieve cumulative production capacities of approximately 3,484 GW for modules, 3,128 GW for cells, 2,630 GW for ingots and wafers, and 2,200 GW-equivalent for polysilicon by 2047.
Manufacturing capacity across the solar value chain is expected to expand rapidly, supported by government-backed projects that mandate the procurement of domestically manufactured solar products.
The expansion could create substantial employment opportunities, with total manufacturing-related jobs increasing from approximately 410,000 currently to 740,000 by 2030 and 3.23 million by 2047. Direct employment in solar PV manufacturing plants could rise from around 140,000 to 1.11 million by 2047.
The share of direct employment in cell, wafer, and polysilicon manufacturing could increase from around 10% currently to approximately one-third by 2030 and more than half by 2047. These segments would generate skilled jobs for technicians, engineers, and chemists.
The report estimates that approximately $89 billion in new solar PV manufacturing investment could be required by 2047 under the Vision 2047 scenario, equivalent to an average of $4.3 billion annually between 2027 and 2047. Nearly 70% of the investment is expected to go toward polysilicon, wafer, and cell manufacturing. India’s Production Linked Incentive (PLI) scheme had already attracted approximately $8.4 billion in investment as of June 2026, with every dollar of incentives mobilizing around $4 in private investment.
A more integrated domestic manufacturing ecosystem could also substantially reduce India’s dependence on imported solar components. The report projects that the country’s annual solar import bill could fall from approximately $4.4 billion currently to zero by 2041 under the Vision 2047 scenario. India could also account for 26.5% of global solar module supply by 2047, compared with a projected 5.9% under the current-policy scenario in 2030.
“India’s solar manufacturing sector stands at a pivotal moment, with the Vision 2047 pathway presenting an unprecedented opportunity to build a globally competitive, integrated manufacturing ecosystem,” Amit Manohar, secretary general of ISMA, said. “The potential to attract $89 billion in investments, generate over 32 lakh jobs and significantly reduce import dependence underscores the strategic importance of strengthening domestic manufacturing across the entire solar value chain. Realising this ambition will require sustained policy support, a predictable demand pipeline, investments in upstream manufacturing and continued efforts to strengthen India’s global competitiveness.”
The report identifies policy certainty, sustained domestic demand, and timely implementation of manufacturing programs as critical to achieving these goals. It calls for maintaining firm timelines under the Approved List of Models and Manufacturers (ALMM), completing PLI-supported projects, expanding rooftop and agricultural solar programs, and accelerating investment in upstream manufacturing. It also highlights the need to develop domestic manufacturing equipment, strengthen technical skills, promote advanced solar cell technologies, establish recycling frameworks, and expand export markets.
The Vision 2047 scenario outlines a phased transition, with cell manufacturing scaling up through 2030, wafer production expanding through 2035, and a fully integrated solar manufacturing value chain emerging thereafter.
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The new issue of pv magazine Global is out now!
Available in print and digital – get your copy today!
Day 1 | Europe’s Solar and Storage Markets 2027: What works where?
Day 2 | Solar + Storage Co-location: Three markets, three business cases
Day 3 | Solar Quality: Which technical risks still need better answers?
Day 4 | Cybersecurity and Procurement: What can European solar projects source in 2027 and beyond?
Thursday, November 5, 2026
10:00 am – 11:00 pm CEST, Berlin, Paris, Madrid
Friday, November 13, 2026
10:00 am – 11:00 am CET, Berlin, Paris, Madrid
As a media partner of Genera 2026, pv magazine will organize and moderate a session in Spanish in Madrid, during International Electrification and Decarbonization Week.
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PNE Sells 250 MW Solar Project In South Africa’s Free State Province  SolarQuarter
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India cabinet clears $1.53 billion programme for energy storage projects  Reuters
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Germany awards 288MW rooftop solar in oversubscribed auction  PV Tech
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Thailand builds a massive floating hydro-solar farm  Reuters
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Yiğit Laçin2026-11-04T08:00:00+00:00
Yiğit Laçin, Chief Executive Officer of YDA Dalaman Airport, explains how 25,500 rooftop solar panels now meet all of the terminal’s annual electricity demand.

Dalaman Airport rooftop solar installation explained
Credit: YDA Dalaman Airport
The rooftop solar programme was developed to turn our sustainability commitments into a practical and measurable investment. Our aim was not only to increase the use of renewable energy, but also to reduce carbon emissions, improve long-term energy performance and make better use of an existing airport asset: the terminal roof.
This approach directly supports our vision of operating a safe, secure and sustainable airport while providing an innovation-driven, high-quality and stress-free passenger experience on the Turkish Riviera. It also shows that environmental responsibility and operational efficiency can progress together.
Using the roof rather than additional land was an important objective. Airports have complex land-use requirements, and available areas must support aviation operations, safety zones and future development. By installing the system on the terminal buildings, we were able to create a major renewable energy facility without increasing the airport’s physical footprint.
The programme was delivered in phases, allowing us to expand capacity while learning from operational data and technical experience. The completed installation has an installed capacity of 14.45MWp and includes 25,500 solar panels across around 74,000 square metres of terminal roof area.
The system is designed to generate more than 20,000MWh of electricity each year. On an annual basis, this is sufficient to meet 100% of the electricity demand of the terminal building.
Achieving this result required more than simply placing panels on available roof space. The project involved detailed engineering, production modelling and careful alignment between generation capacity and the terminal’s actual energy profile. Structural suitability, roof access, waterproofing, electrical integration, safe maintenance routes and the continuity of terminal operations all had to be considered.

Credit: YDA Dalaman Airport
The most visible environmental benefit is the reduction in emissions. The programme prevents approximately 8,500 tonnes of CO2 emissions each year, an impact comparable to the annual carbon absorption of around 380,000 trees.
There are also clear operational benefits. On-site generation reduces the airport’s exposure to energy price volatility and lowers its reliance on externally supplied electricity. It provides a more predictable foundation for long-term energy planning and makes energy performance a more visible part of airport management.
The rooftop model also avoids the environmental and planning impacts that can arise from using additional land. This is especially important in airport environments, where land has operational, ecological and development value.
The panels contribute to energy efficiency as well as electricity generation. By covering a large part of the terminal roof, they create a shading effect that reduces direct solar heat gain on the building.
This is particularly valuable at Dalaman, where high summer temperatures and strong solar exposure increase cooling demand during the busiest months of the year. The additional shade provided by the solar installation helps reduce the heat load on the terminal and supports an estimated reduction of around 10% in cooling-related energy demand.
This combined benefit was central to the project. The roof is not only producing clean electricity; it is also helping the building use less energy. It demonstrates why renewable energy projects should be assessed as part of the overall building and operational system, rather than as stand-alone installations.

Credit: YDA Dalaman Airport
The roof is not only producing clean electricity; it is also helping the building use less energy.”
Integrating a large solar installation into an operational airport terminal required careful planning. The terminal had to remain fully functional throughout the project, with no compromise to passenger safety, service continuity or aviation security.
Construction activities therefore had to be phased and coordinated around airport operations. Access to roof areas, the movement of materials, electrical works and contractor activities were managed through detailed planning and close cooperation between technical, operational, safety and security teams.
Another important challenge was integrating the new system into the existing terminal structure and electrical network. Airports operate continuously and depend on stable power for critical systems. Installation and connection works therefore required controlled implementation, testing and coordination to avoid disruption.
Maintenance was also considered from the design stage. Safe access, inspection routes, cleaning requirements and performance monitoring are essential to protect output over the lifetime of the system.

Credit: YDA Dalaman Airport
The rooftop solar programme is a major part of Dalaman Airport’s wider decarbonisation and sustainability strategy, but it is not an isolated project. Our broader approach includes energy efficiency, responsible waste and water management, recycling, environmental performance monitoring and the reduction of unnecessary consumption.
The project also supports our work under the Airport Carbon Accreditation programme. Dalaman Airport has achieved Level 3+ accreditation, and we continue to assess the next steps in our carbon management journey. The scale of the rooftop solar investment gives us a strong platform for deeper emissions reduction and more advanced energy management.
More importantly, it helps make sustainability part of daily airport operations. Energy data, technical performance and environmental impact can be followed more closely and used to guide future investment decisions.
A key lesson is that roof space can be a strategic asset. However, every airport is different, and not every roof will be suitable for a project of this scale. Structural capacity, roof geometry, local climate, grid conditions, energy demand and operational restrictions must all be assessed carefully.
Another important consideration is to start with reliable data. A clear understanding of electricity consumption, seasonal peaks and the terminal’s operating profile is essential when defining the right system capacity.
A further aspect is to involve operational teams early. Renewable energy projects at airports cannot be treated only as engineering projects. Safety, security, maintenance, information technology, procurement, finance and airport operations all have an important role.
Finally, airports should look beyond the electricity generated. Shading, cooling performance, land-use efficiency, maintenance requirements and long-term operating costs can materially affect the overall value of the project.
Renewable energy projects at airports cannot be treated only as engineering projects.”
Our next priorities are to build on this renewable energy foundation through stronger energy monitoring, automation and data-led optimisation. We are also assessing how artificial intelligence and advanced control systems can help identify consumption patterns, improve equipment performance and support faster operational decisions.
Further energy-efficiency measures, continued improvements in water and waste management, and the next stages of our carbon accreditation journey will remain important. We will also continue to assess sustainable infrastructure investments according to their measurable environmental and operational value.
For Dalaman Airport, achieving 100% of terminal electricity demand through rooftop solar is an important milestone, but not the end of the journey. It provides a practical example of how airports can use existing infrastructure, technology and cross-functional cooperation to deliver meaningful progress towards a lower-carbon future.

Credit: YDA Dalaman Airport
 
2026-10-30T15:00:00Z
Nicolas Notebaert
2026-10-29T09:09:00Z
Gabriel Higgins
2026-10-20T09:52:00Z
Gabriel Higgins
2026-10-16T08:00:00Z
Gabriel Higgins
2026-10-14T08:00:00Z
Christopher Walker
2026-10-13T11:45:00Z
Gabriel Higgins
2026-11-17T14:00:00
Sponsored by Smiths Detection
2025-12-11T07:00:00
Sponsored by Smiths Detection
2024-12-16T14:37:20
Sponsored by Mumbai Chhatrapati Shivaji International Airport (BOM)
2026-06-29T07:09:00
Sponsored by Leonardo S.p.A.
2026-07-14T06:00:00
Sponsored by NACO, Contributor Esther Kromhout
2026-09-10T13:31:00
Sponsored by IDEMIA and Veovo
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Cloudy with showers. High 66F. Winds S at 10 to 20 mph. Chance of rain 70%..
Cloudy in the evening, then off and on rain showers after midnight. Low around 45F. Winds SW at 10 to 15 mph. Chance of rain 40%.
Updated: November 4, 2026 @ 1:15 am
Wexford County Administrator Joe Porterfield addresses the Wexford County Board of Commissioners during a meeting held on Wednesday, Oct. 21, 2026.

Staff Writer/Reporter
Wexford County Administrator Joe Porterfield addresses the Wexford County Board of Commissioners during a meeting held on Wednesday, Oct. 21, 2026.
• The Wexford County Board of Commissioners will consider a $27,109.60 budget amendment to complete radio system upgrades in four patrol vehicles. Commissioners also will consider using a Michigan State Police grant to upgrade fingerprinting equipment at the Wexford County Jail.
• The board will review a request from its legal counsel to waive potential conflicts of interest involving the firm’s representation of both Wexford and Grand Traverse counties in connection with the Shipyard Solar project.
CADILLAC — The Wexford County Board of Commissioners is scheduled to discuss and multiple agenda items connected to the Wexford County Sheriff’s Office during its upcoming meeting Wednesday.
This includes a vote on a budget amendment of more than $27,000 to pay for upgrades to four patrol vehicle radio systems. Commissioners also will vote on upgrading the fingerprinting capabilities at the Wexford County Jail through a Michigan State Police grant.
Wexford County Sheriff Trent Taylor said the total cost of the vehicle radio upgrades is $27,109.60. He said the work will complete the upgrades to the county’s patrol vehicle fleet. While these will be the last vehicles needing radio upgrades, Taylor said the issue likely will need to be revisited in a few years when additional upgrades are necessary related to changes in the technology used.
As for the fingerprinting equipment, Wexford County Jail Administrator Lt. Michael McDaniel said he applied for a grant through the MSP that will allow the county to be reimbursed for the cost of upgrading the Identix fingerprinting machine at the jail.
In addition to a new computer that will run an updated operating system, McDaniel said the grant will allow for the purchase of a new palm scanner, which is used to capture digital fingerprints.
“We currently have one, but this upgrades the one we have. Our current system is not Windows 11 compatible, and this upgrade will allow for it,” McDaniel said.
Also during the meeting, commissioners are scheduled to discuss another waiver of conflict and consent to representation regarding the Shipyard Solar project.
The commissioners are being asked to waive any potential conflict of interest involving the law firm representing both Wexford and Grand Traverse counties in their review of the Shipyard Solar LLC project.
In a letter included in the board’s Nov. 4 meeting agenda packet, Cohl, Stoker & Toskey, P.C., said both counties have requested its legal representation regarding the project. While the firm said it does not believe an actual conflict currently exists, it acknowledged that the counties could eventually disagree over its legal opinions regarding the project.
The firm is asking each county board to review the potential risks and implications of the joint representation and, if agreeable, formally waive any potential conflict.
The board chair would sign the letter to document the county’s consent.
Last month, commissioners approved waiving a potential conflict involving the county’s bond counsel, Dickinson Wright PLLC. The bonds are related to construction of the Wexford County Jail.
The request from the law firm asked the county to acknowledge that there would be no conflict related to its connection with the Ranger Power solar project.
During the board’s discussion last month, Wexford County Administrator Joe Porterfield said he had reached out to the county’s legal counsel at Cohl, Stoker & Toskey. If the county were drawn into any legal issue related to the solar farm, he said, the firm would represent Wexford County.
The board is scheduled to meet at 4 p.m. Wednesday in the commissioners room on the third floor of the Wexford County Courthouse, 437 E. Division St. The meeting also will be available on YouTube after its conclusion by searching for “Wexford County Board of Commissioners.”
rcharmoli@cadillacnews.com
Staff Writer/Reporter
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Jinko Solar Celebrates 20 Years of Innovation with the Official Launch of Tiger Neo 3 in Morocco  SolarQuarter
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© 2025 THE COOL DOWN COMPANY. All Rights Reserved. Do not sell or share my personal information. Reach us at hello@thecooldown.com.
“We are also on a hill so exposed enough.”
Photo Credit: iStock
A U.K. solar owner recently voiced a common fear among people considering panels — that they may not hold up in strong winds. For another solar owner whose panels outlasted Storm Eowyn, however, the solar benefits clearly outweighed any extreme weather risks. 
In r/SolarUK, a Reddit user posted what they called a “click-bait” picture of solar damage from Storm Eunice, a record 2022 storm that resulted in an “incredibly rare Red alert across southern and eastern England and south Wales” and caused widespread structural damage, including tearing roofs off buildings, according to Earth.org and the Met Office.  
“Has anyone had their [panels] blown off? I’m end [terraced] and the wind hits the gable end and whips up a hell of an updraft with lots of high vs low pressure at the tile,” the poster worried. 
Solar is increasingly popular because it’s one of the best ways to save money on home energy, and solar leases in particular can deliver hundreds of dollars in monthly savings without upfront costs—so it’s understandable why people want to ensure their system is resilient. 
EasyHome‘s free explorer tool can help U.S. homeowners discover potential savings from vetted installers in their area. In this case, Reddit users reassured the original poster that they shouldn’t worry about their panels, as long as they were installed properly. 
“Had ours for 8 years. Loads of storms including eowyn worst in 100 years. We are also on a hill so exposed enough. All fine,” one person said. 
“A structure that also happened to have solar panels got blown by a storm,” another said.
The solar experts agree: Panels are designed to survive extreme weather, including hurricanes.
With energy prices through the roof, there’s never been a better time to go solar — and EasyHome can help you find the best prices from the best installers in your area.
EasyHome takes the guesswork and headaches out of energy upgrades by showing you estimated savings from a network of vetted local partners. To get started, just enter your ZIP and share a few details about your home — seeing your estimate is really that easy.
“When solar panels are attached to your roof, your solar installer will use long, strong lag bolts that attach the racking directly to your rafters, ensuring a strong connection between your roof and the solar power system. As long as your rafters stay attached to your house, your solar panels should have no problem surviving a hurricane,” Palmetto detailed, including data from the National Laboratory of the Rockies, formerly the National Renewable Energy Laboratory.
EasyHome can also help homeowners explore backup battery storage options. Pairing solar with a battery can maximize savings while allowing you to power your home with solar when the grid goes down, provided the system is configured for backup operation.
“We hear the wind behind our panels rattling the cables and it sets my nerves going! Solar panels seem solid, though,” a Reddit user concluded. 
Questions about solar panels in rough weather go beyond wind resistance. 
• In Texas, 16 solar panels survived hail that totaled a homeowner’s roof and car.
• On a windy U.K. hill, a homeowner weighed a garden turbine against solar.
• A U.K. owner’s first gray, rainy day showed how darkness limits solar generation.
• A U.K. homeowner seeking solar power under winter clouds encountered blunt feedback from off-gridders.
• In the U.K., three darkened solar cells prompted suggestions of micro-cracks or faulty busbars.
Get TCD’s free newsletters for easy tips, smart advice, and a chance to earn $5,000 toward home upgrades. To see more stories like this one, change your Google preferences here.
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A research team led by scientists at China’s Southeast University has developed a self-powered photovoltaic-thermoelectric generator (PV-TEG) system that integrates hotspot detection, local thermal management, and wireless monitoring into a TEG array.
Thermoelectric generators (TEGs) convert heat into electricity through the Seebeck effect, which occurs when a temperature difference between two dissimilar semiconductors generates a voltage. TEGs are commonly used in industrial applications to recover waste heat and convert it into electricity. However, their high costs and limited efficiency have so far restricted their wider adoption.
In PV-TEG systems, PV panels generate electricity during the day, while TEGs harness temperature differences to produce additional electricity.
“The key innovation of our research is that we go beyond the conventional role of TEGs as waste-heat harvesters,” corresponding author Jingming Cai told pv magazine. “We demonstrate that the electrical signals generated by these devices can also reveal where thermal anomalies occur within a PV module.”
Cai said that by integrating four TEGs into a compact array, the researchers developed a system that combines hotspot localization, passive thermal management, energy harvesting, and wireless monitoring. “Essentially, we are turning the waste heat of solar panels into a source of both energy and diagnostic information,” he said.
The researchers first developed a three-dimensional multiphysics model of a 500 mm × 500 mm PV region equipped with four rear-mounted TEGs and an aluminum heat sink. The model coupled heat transfer and thermoelectric conversion under baseline conditions of 1,000 W/m2 irradiance and an ambient temperature of 25 C.
The team placed a 20 mm × 20 mm heat source at nine positions and mapped normalized TEG voltage changes to hotspot coordinates. It then evaluated localization accuracy at three additional positions, compared cooling performance with that of a bare PV module, and assessed sensitivity to environmental conditions and thermal contact resistance.
“Multiphysics simulations clarified the coupling among hotspot position, thermoelectric voltage response, and local cooling,” the researchers said. “Distinct hotspot locations generated differentiated four-channel voltage patterns, enabling quantitative mapping from normalized voltage responses to two-dimensional coordinates. The simulated local temperature reduction ranged from 8.15 K to 12.40 K.”
The researchers then conducted outdoor tests in Taizhou, eastern China, installing the PV-TEG system on a rooftop array at a telecommunications facility. They monitored TEG temperatures, supercapacitor voltage, and wireless transmission events from approximately 8 a.m. to 6 p.m. The monitoring electronics activated when the capacitor voltage reached 4.0 V and switched off at 2.8 V to allow recharging.
The team used infrared imaging to compare local point temperatures and regional average temperatures with those of a reference PV region. To evaluate hotspot localization, the researchers applied black tape at three positions to create controlled thermal disturbances, measured the voltage responses of the four TEGs, and reconstructed the anomaly coordinates. They tested each position three times, using infrared imaging to verify the location and temperature of each anomaly.
“What surprised us most was how accurately a small array of just four thermoelectric generators could identify the location of a thermal anomaly,” Cai said. “In our outdoor experiment, we achieved a localization error of approximately 9.93 mm. Meanwhile, the integrated system reduced the local PV surface temperature by up to 7.7 C at the measured point, with an average reduction of 5.4 C across the monitored region.”
Cai said another encouraging result was that the system could operate without an external power supply for the monitoring electronics, completing approximately 45 wireless transmissions during a 10-hour daytime field test. “These findings suggest that even relatively small amounts of photovoltaic waste heat can be valuable when converted into sensing capabilities rather than simply additional electricity,” he said.
Cai said the team now plans to investigate how the system performs under electrically induced PV hotspots and more complex outdoor operating conditions. “Our long-term vision is to make solar panels capable of monitoring their own thermal health, identifying potential faults at an early stage, and reducing the need for energy-intensive monitoring infrastructure,” he concluded.
The researchers described the system in “A self-powered PV-TEG system for integrated hotspot monitoring and local thermal management based on thermoelectric voltage response,” which was recently published in Applied Thermal Engineering. Scientists from China’s Southeast University and Australia’s University of Technology Sydney contributed to the study.
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Thursday, November 5, 2026
10:00 am – 11:00 pm CEST, Berlin, Paris, Madrid
Join our four-day virtual event exploring Europe’s solar and storage markets, challenges, and opportunities.
Day 1 | Europe’s Solar and Storage Markets 2027: What works where?
Day 2 | Solar + Storage Co-location: Three markets, three business cases
Day 3 | Solar Quality: Which technical risks still need better answers?
Day 4 | Cybersecurity and Procurement: What can European solar projects source in 2027 and beyond?
Friday, November 13, 2026
10:00 am – 11:00 am CET, Berlin, Paris, Madrid
As a media partner of Genera 2026, pv magazine will organize and moderate a session in Spanish in Madrid, during International Electrification and Decarbonization Week.
Monday, November 23, 2026
11:00 am – 12:00 pm CEST, Berlin, Paris, Madrid

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AIKO Unveils Gen 4 Solar Panels and Signs 1 GW of Australian Agreements  Energy Matters
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New solar project to power 700 homes in Cherry Valley  Yahoo
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The latest trio of additions to Côte d’Ivoire’s growing solar PV fleet have started construction, as the government’s aim of boosting renewable energy supply by 2030 gains traction.
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As solar projects increasingly become long-term energy assets rather than simple equipment installations, engineering quality will continue to grow in importance. The next generation of solar modules must perform not only on the day of installation, but throughout their operational lifetime. Sunora Solar's vision is to be part of this evolution.
November 04, 2026. By News Bureau

KP Group’s Dr. Faruk Patel on Building Integrated Clean Energy Ecosystem Through KP 3.0

Venkatesh Kumar, Sungrow India, Explains Shift Towards Intelligent Storage-Enabled Power System

Valeo’s Vaibhav Mutha on Scaling India’s Domestic PV Ribbon Manufacturing

Dhash’s Bhupendra Singh Rawat on Building India’s Solar Component Ecosystem

Kimbal Targets Australia and Southeast Asia for Global Expansion

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Solar aid for thousands of Virginia households remains frozen despite court orders to restore it  Yahoo
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ANI
03 Nov 2026, 16:03 GMT+10
New Delhi [India], November 3 (ANI): India’s renewable energy expansion has saved an estimated USD 100 billion in fossil fuel import costs over the past decade and could save another USD 100 billion in the next five years, European Union Ambassador to India Jean-Eric Paquet said on Tuesday.
Addressing the Bharat RE Summit & Expo 2026, Paquet highlighted the economic benefits of India’s transition towards renewable energy, particularly in reducing dependence on imported fossil fuels and strengthening energy security.
He said that without the expansion of non-hydro renewable energy capacity since 2010, India’s dependence on fossil fuel imports would have been approximately 50 per cent higher than current levels.
“We calculated what India’s import dependency on fossil fuels, coal and gas would be. If non-hydro renewables were not built since 2010, today, the import dependency would be 50% higher in the order of 110 million tons of coal equivalent,” he said. 
The Ambassador further noted that the additional fossil fuel requirement avoided through renewable energy could double by 2030.
“This is the benefit to energy security diversification, and it has very important economic implications. If you look at the historical prices, we calculated that cumulative…” he added.
Paquet also highlighted India’s renewable energy investments have helped the country avoid substantial expenditure on fossil fuels over the past decade.
“India saved USD 100 in a decade, and most importantly, it will save another USD 100 billion in the next five years, and if you think that in the next five years there will be investment for USD 200 billion in renewables, you could say, well, half of it is kind of financed by these savings,” he said. 
He said the findings underline the importance of renewable energy expansion in strengthening India’s energy diversification and long-term energy security. 
The EU Ambassador further highlighted India’s growing role in global solar photovoltaic (PV) manufacturing, saying the country has emerged as the world’s second-largest producer of solar PV, with significant capabilities in module manufacturing and expanding capacity in cells and wafers. 
Highlighting India’s contribution to solar manufacturing outside China, Paquet said the country already accounts for approximately 50 per cent of non-China module production, while its share in wafer manufacturing could reach 40 per cent by 2030. 
“Now, this is the result of comprehensive industrial strategy through the production-linked incentive and also approved list of models and manufacturers that have been a real breakthrough in this field,” he said.
Emphasising the global significance of India’s expanding solar manufacturing capacity, Paquet added, “I insist this is not just important for India. This is important for the whole world.” (ANI)

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Slovenian state-owned energy company Holding Slovenske Elektrarne (HSE) has administered a tender for a solar-plus-storage project.
Available tender details state the tender covers a 1.38 MW solar power plant to be tied to a 1.25 MW/5 MWh battery energy storage system.
The project will be built within the area of Kamnolom Zagorje, a closed municipal waste landfill located in the municipality of Zagorje ob Savi, central Slovenia. It forms part of HSE’s wider work in developing renewable energy projects in brownfield areas in Slovenia’s Zasavje region.
The chosen contractor will be responsible for the design, supply, assembly, testing and connection of the hybrid plant.
HSE announced securing a building permit for the project in late September. At the time, it said part of the funds for the project will be provided by the EU’s Just Transition Fund.
“As part of the project, measures to drain stormwater more efficiently and reduce its seepage into the body of the landfill will also be implemented to further contribute to the appropriate and sustainable management of the area,” HSE said. “The building permit is an important milestone on the path towards implementing the investment, which is planned for 2027.”
Prospective bidders can submit questions requesting additional information until November 10. The deadline for applications, which must be submitted electronically, is November 19.
Slovenia’s cumulative solar capacity stood at 1.57 GW by the end of last year after installing 146.5 MW in 2025.
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Thursday, November 5, 2026
10:00 am – 11:00 pm CEST, Berlin, Paris, Madrid
Join our four-day virtual event exploring Europe’s solar and storage markets, challenges, and opportunities.
Day 1 | Europe’s Solar and Storage Markets 2027: What works where?
Day 2 | Solar + Storage Co-location: Three markets, three business cases
Day 3 | Solar Quality: Which technical risks still need better answers?
Day 4 | Cybersecurity and Procurement: What can European solar projects source in 2027 and beyond?
Friday, November 13, 2026
10:00 am – 11:00 am CET, Berlin, Paris, Madrid
As a media partner of Genera 2026, pv magazine will organize and moderate a session in Spanish in Madrid, during International Electrification and Decarbonization Week.
Monday, November 23, 2026
11:00 am – 12:00 pm CEST, Berlin, Paris, Madrid

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During a panel discussion at pv magazine USA Week 2026, industry leaders from Tesla, FranklinWH, and Ohm Analytics detailed how post-ITC economics, virtual power plants, and grid capacity constraints are driving residential solar installers to adopt storage-first business models.
The residential solar market experienced a 19% year-over-year decline in installation volume, but residential storage deployments held steady with nearly 1 GWh installed in Q2 2026. Data presented by Ryan Feeney, partner at Ohm Analytics, showed that this stability pushed the national battery attachment rate to 49%.
In California, projects installed under the state’s NEM 3.0 tariff reached an 80% storage attachment rate, while Texas experienced a 132% year-over-year increase in storage installations, with standalone battery retrofits making up roughly 75% of that growth.
“We recently released our quarterly report and we actually highlighted this trend as one of the defining trends of the year,” Feeney said. “The residential solar market was down 19% year-over-year, but close to a gigawatt-hour of storage was installed in Q2, making it roughly flat.”
As export compensation rates decline under net metering revisions nationwide, panel speakers emphasized that storage has shifted from an optional add-on to the central driver of residential project economics.
Ronnie Pettersson, vice president of product and application engineering at FranklinWH Energy Storage, noted that installer sales presentations have shifted at the kitchen table from array sizing toward calculating exact household kilowatt-hour storage needs. Pettersson attributed this to growing consumer concerns over extreme weather outages, rising retail electricity prices, and localized power grid stress from artificial intelligence data centers.
“It really starts at the kitchen table where the installers’ salespeople are talking from ‘how much solar do you want to have on the roof’ to ‘how many batteries do you really need,’” Pettersson said.
Scaling VPP capacity and real-world fleet performance 
With utility distribution grids facing unprecedented load growth, aggregated distributed energy resource fleets are stepping in as firm grid capacity assets. Doug Middleton, utility and virtual power plant business development lead at Tesla, reported that Tesla now manages over 1.5 million Powerwalls globally, with 2.5 GW representing nearly 5 GWh of storage capacity currently enrolled in active VPP programs.
Middleton pointed to recent summer grid dispatches in California, where Tesla aggregated more than 600 MW of coordinated capacity across multi-hour events. The California Powerwall VPP fleet expanded its overall capacity by 50% year-over-year, demonstrating the speed at which modular residential storage can scale compared to transmission-scale assets. In Puerto Rico, Tesla’s aggregated Powerwall network acts as a continuous marginal generation resource to prevent local utility rolling blackouts. 
“This is not demand response, right? It’s demand-sited generation, which gives it a different capability set than I think historically grid operators are used to from distributed assets,” Middleton said. “Having the political will, the ongoing load growth—like the pressure that will keep that kind of cost pressure there in the load growth from large loads—alongside capability and scale is really giving us a chance to go out and compete alongside real resources and not kind of be some pilot project.”
Third-party performance verification data from the Connecticut Green Bank shows that FranklinWH and Tesla battery fleets achieved over 90% participation rates during requested utility dispatches, while competing original equipment manufacturers registered participation rates below 70%.
Financing models and wholesale market access
Integrating VPP program revenues directly into customer financing contracts offers a path to significantly expand the total addressable market for residential storage. Ohm Analytics estimates that 30% to 35% of residential batteries are currently enrolled in a VPP program. 
Program financial compensation structures are expanding rapidly across major markets. In Massachusetts, the Connected Solutions program offers up to $400 per kilowatt-year for batteries deployed in congested distribution circuits, combining a base incentive with a $125 per kilowatt-year distribution service adder. ERCOT program participation in Texas yields up to $325 annually, while New Jersey’s GridSmart program provides a $5,000 upfront rebate alongside zero-interest bill financing. In California, Ava Community Energy offers up to $6,000 in upfront battery installation rebates for qualifying low-income customers.
Middleton argued that third-party ownership and leasing providers must incorporate these anticipated grid service revenues directly into upfront consumer pricing. Monetizing grid services at the point of sale can reduce a homeowner’s monthly battery lease payment from $200 per month down to $100 per month.
“If we as an OEM and we as a service provider in conjunction with our partners, our EPCs, our financiers, if we can actually just offer that as an upfront discount, you now go from call it a $200 a month payment to buy these down to a $100 a month payment,” Middleton said. “And you just think about the adoption that opens up in terms of the number of homeowners.”
However, legacy wholesale market rules continue to hinder scaling. Middleton highlighted that regional transmission operators like CAISO and PJM still operate under rules designed for legacy demand-response assets, which treat battery aggregations solely as load reduction and prevent home batteries from receiving wholesale market compensation for exporting power back to the grid.
“There’s a lot of policies that were set before battery storage was really a technology, and the way we participate is through mechanisms designed for large loads,” Middleton said. “The fact that a distributed battery can’t get paid for exports in wholesale markets is like such an obvious win.”
Legislative workarounds are beginning to emerge, including a recent New Jersey law allowing commercial data centers to contract directly with distributed energy resource aggregators, enabling large-scale flexible capacity deals like Google’s 100 MW PJM capacity contract with Voltus.
Hardware bottlenecks and standardizing installation hardware
To bring down balance-of-system and customer acquisition costs, manufacturers are targeting main service panel bottlenecks through standardized hardware. Pettersson highlighted meter collar adapters and microgrid interconnection devices, such as the UR-MID standard currently being formalized with NEMA, as critical tools to bypass main panel upgrades and eliminate separate disconnect switches.
“What you don’t have to do is install, for example, a disconnect means to island the home,” Pettersson said. “And that makes it easier for the battery to act as the backup for the home as an upgrade solution.”
As commercial data center power demand compresses utility interconnection timelines, distributed batteries represent a rapidly deployable alternative. Panels speakers noted that while legacy infrastructure upgrades often require years of permitting, distributed battery fleets can be deployed within months to deliver immediate capacity relief.
“Focusing on storage and diversifying their offerings, getting creative—I’d say five years out, we expect storage to be the standard model,” Feeney said. “With net metering cuts reducing the value of exports, utilities launching VPP programs, successful contractors are going to be the ones that sell batteries, enroll them, and can explain it to homeowners.” 
Watch the full panel below at 105:43:
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The financing follows a $183 million debt package secured earlier this year for the project
November 3, 2026
Follow Mercom India on WhatsApp for exclusive updates on clean energy news and insights
Arevon Energy, a U.S. energy developer, owner, and operator, has secured a $120 million tax equity commitment from Wells Fargo Bank for its 124 MW Big Muddy Solar project in Jackson County, Illinois.
Construction of Big Muddy Solar began in 2025, and the project is scheduled to begin commercial operations by the end of 2026. More than 250 workers were involved in constructing the facility.
Arevon said the transaction is its second tax equity financing with Wells Fargo. The company has completed $5.2 billion in project financings over the past several years. The financing will allow Arevon to monetize the project’s tax attributes, including depreciation and investment tax credits, as the project advances toward commercial operations.
The transaction follows a $183 million debt package secured for Big Muddy Solar in February of this year, which included a tax equity bridge loan, construction-to-term loan, and a letter of credit.
Latham & Watkins served as sponsor counsel for the transaction, while Husch Blackwell served as sponsor local counsel. Hunton Andrews Kurth served as tax equity counsel, and Bryan Cave Leighton Paisner acted as lender and tax equity local counsel.
Arevon is also developing, constructing, and operating other energy projects in the U.S. Midwest. The company recently began operations at the 430 MW Kelso Solar project in Missouri and the Ratts 1 and Heirloom solar projects in Indiana, which have a combined capacity of 264 MW. Arevon has also secured three 20-year renewable energy credit contracts for the 200 MW/275 MW Panther Energy project under development in Illinois.
In Indiana, Arevon developed and managed the construction of the 251 MWd Gibson Solar project and the 228 MW Posey Solar project on behalf of local utilities.
In 2026, the company closed a $920 million financing package for its 300 MW/1,200 MWh Nighthawk energy storage project in Poway, California. The project is supported by a long-term agreement to deliver resource adequacy capacity to Pacific Gas and Electric Company.
Announced large-scale solar project funding increased by 75% in the first nine months of 2026 compared with the funding raised in the same period in 2025, according to Mercom’s recently released 9M and Q3 2026 Solar Funding and M&A report.
Renu
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Canais Plataforma:
MUMBAI, India, Nov. 4, 2026 /PRNewswire/ — Avaada Electro Limited, the solar manufacturing arm of Avaada Group, has achieved a significant milestone in India's clean energy manufacturing journey, with 7,117 MW (7.117 GW) of N-type TOPCon solar cell manufacturing capacity enlisted under the Ministry of New and Renewable Energy's (MNRE) 13th revision of the Approved List of Models and Manufacturers (ALMM) List-II, dated 28 October 2026.
The enlistment marks an important step in Avaada Electro's journey towards building a globally competitive solar manufacturing enterprise and strengthening India's domestic solar technology ecosystem.
At a time when the world is seeking more diversified and resilient clean energy supply chains, India's ability to manufacture advanced solar cells at scale is becoming increasingly important. Avaada Electro's Butibori facility in Maharashtra represents a significant contribution to this national ambition.
Advanced Technology: Making Every Watt Count
A key highlight of the latest ALMM enlistment is Avaada Electro's G12 N-type TOPCon solar cell technology, with manufacturer-declared maximum cell efficiency reaching up to 26.8% and the highest listed average cell efficiency of 25.89%.
The company's G12 full-cell model has a declared maximum power output of 11.81 watts per cell.
These technical parameters reflect the potential of advanced TOPCon technology to generate more electrical power from a given silicon cell area, supporting the development of higher-power solar modules.
As solar technology advances, improving conversion efficiency remains an important pathway towards better utilisation of materials, manufacturing resources and installation infrastructure.
For Avaada Electro, the focus is not simply on achieving higher technical specifications, but on translating technological progress into consistent product quality, dependable performance and competitive manufacturing economics.
Manufacturing at Scale: Strengthening India's Solar Supply Chain
With 7.117 GW of annual enlisted nameplate capacity, Avaada Electro's Butibori manufacturing facility actual production and saleable output will depend on operating utilisation, manufacturing yields and product mix.
The scale of this manufacturing platform strengthens Avaada Electro's ability to serve India's expanding solar industry, including module manufacturers, renewable energy developers and engineering, procurement and construction companies.
It also contributes to the development of domestic manufacturing capabilities at a time when India is working to strengthen supply-chain resilience, promote industrial self-reliance and reduce dependence on imported solar components.
Beyond Capacity: Building a Culture of Manufacturing Excellence
Avaada Electro believes that manufacturing leadership cannot be measured by installed capacity alone.
Long-term competitiveness requires continuous improvement in cell efficiency, production yields, product reliability, manufacturing productivity and cost per watt.
The company is building its manufacturing approach around three fundamental principles:
Through its continued investment in advanced TOPCon technology and manufacturing capabilities, Avaada Electro aims to build a dependable domestic supply platform capable of competing on quality, technology and cost.
Chairman's Statement
Commenting on the milestone, Vineet Mittal, Chairman and Whole-time Director, Avaada Electro Limited, said, "India's clean energy future cannot depend only on how much solar power we install. It must also depend on how much technology we develop, how much we manufacture ourselves, and how effectively we compete with the world.
Our 7.1 GW TOPCon solar cell manufacturing enlistment is an important milestone in that journey.
But manufacturing leadership is not about building the biggest factory. It is about making better products, improving efficiency every day, maintaining uncompromising quality and earning the trust of customers through consistent performance.
At Avaada, we believe that every improvement in technology must ultimately create value for our customers, for the environment and for our country. Our ambition is simple to Make in India. Compete with the world. Make every watt count. This milestone is not the destination. It is another step towards demonstrating that India can build advanced clean energy technology at scale and with globally competitive standards."
Supporting India's Energy Security and Manufacturing Ambitions
India's energy transition presents an opportunity that extends far beyond renewable power generation. It offers the country a pathway to develop advanced industrial capabilities, create skilled employment, strengthen domestic supply chains and become an important participant in global clean energy manufacturing.
Avaada Electro aims to contribute to this transformation by combining manufacturing scale, technological development, disciplined operations and long-term customer relationships.
As the solar industry evolves, the companies that succeed will be those capable of delivering not only more manufacturing capacity, but also greater productivity, consistent quality and better value from every watt.
For Avaada Electro, the 7.1 GW ALMM enlistment represents an important foundation for that journey.
About Avaada Group
Avaada Group is an Indian integrated energy transition company with businesses spanning renewable power generation and advanced solar manufacturing. Through Avaada Electro, the Group is developing domestic solar photovoltaic cell and module manufacturing capabilities, with a focus on advanced N-type TOPCon technology, manufacturing excellence, product reliability and customer value.
The Group is committed to supporting India's energy security, clean energy transition and ambition to become a globally competitive manufacturing economy.
For further information, visit www.avaada.com
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Corporate funding, public market financing, and debt investments in the global solar sector experienced 45% year-over-year growth through three quarters of 2026, said Mercom Capital Group.
The $25.1 billion raised across 170 deals represents substantial volume growth from the $17.3 billion secured across 127 deals in the first nine months of 2025.
“Solar corporate funding increased sharply in the first nine months of 2026, driven largely by debt financing. Public-market fundraising also improved, while both corporate M&A and solar project acquisitions increased as companies expanded their portfolios, recycled capital, and consolidated their operations,” said Raj Prabhu, CEO of Mercom Capital Group.
Driving much of this expansion, announced solar debt financing totaled $20.4 billion across 80 deals through three quarters of 2026, marking a 61% increase compared to the $12.7 billion raised over 60 deals during the same period in 2025. Public market financing similarly strengthened, totaling $2.7 billion across 32 deals, up from $1.7 billion across 12 deals in 9M 2025.
Conversely, global venture capital funding for the solar sector contracted, reaching $2.0 billion across 60 deals through three quarters of 2026, down 31% compared to the $2.9 billion raised over 55 deals in the year-ago period. Solar downstream companies accounted for $1.3 billion across 39 deals during this timeframe.
The top VC transactions through three quarters of 2026 were led by Inox Clean Energy with $343 million, followed by Nexamp at $180 million, Clean Max Enviro Energy Solutions at $165 million, Amarenco at $150 million, and Erco at $129 million.  
Corporate mergers and acquisitions activity expanded year-over-year, tracking 88 solar M&A transactions through three quarters of 2026 compared to 76 transactions in 9M 2025. Large-scale solar project acquisition activity also trended upward, registering 205 transactions compared to 166 transactions in the year-ago period. In terms of capacity, a total of 34.4 GW of solar projects changed hands through three quarters of 2026, up from 29 GW in 9M 2025.  
Project developers and independent power producers anchored acquisition activity as the most active buyers of solar projects in Q3 2026, picking up 6.7 GW, while investment firms secured 1.2 GW. Other buyers, including distributors and engineering and construction companies, acquired 852 MW, and utilities picked up 362 MW of projects.
Notable corporate transactions over the period included Inox Solar Americas acquiring Boviet Solar for $750 million, Drax acquiring Bluefield Solar Income Fund for $737 million, NextPower acquiring Zimmermann PV-Steel Group for $378 million, Greenbacker acquiring a 59.14% stake in Dasolar for $375 million, and strategic acquisitions by TCL Solar.
“Despite the higher activity, financing conditions remained challenging. Changes in U.S. tax policies, trade restrictions, rising equipment costs, and uncertainty over project economics complicated investment decisions. Capital remained available, but access to financing and investor appetite remained uneven across the industry,” said Prabhu.
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Watch the launch video: MISA Group leads the development of Zimbabwe’s first utility-scale wind farm, a USD 300-million hybrid power project.


Zimbabwean developer Tatanga Energy and Modaso Energy, part of Geneva based MISA Group, have announced plans for a US$300 million hybrid renewable energy project in the Guruve-Mazowe (Chikonyora) area of Mashonaland Central Province.
The 228MW facility will combine 128MW of wind, 100MWac of solar PV and a 50MW/100MWh battery energy storage system, all connected through a single 100MW grid connection. Once operational, it is projected to produce around 550GWh of clean power each year, equal to about 5% of Zimbabwe’s total electricity demand.
The project is described as Zimbabwe’s first utility scale wind farm and the first site in sub-Saharan Africa outside South Africa to integrate wind, solar and battery storage at this scale.
Standard Bank has been appointed to arrange project debt, and a term sheet has been agreed. ZESA Holdings, the national utility, is expected to be the primary power buyer through ZETDC under a planned long term power purchase agreement. Zim GreenCo, part of Africa GreenCo, has signed Heads of Terms for a long term offtake contract and will trade power domestically and regionally through the Southern African Power Pool (SAPP). Financial close is targeted for mid 2027, with commercial operations expected in 2029.
“As a contracted buyer and trader, ZimGreenCo gives Guruve-Mazowe a second route to market alongside ZESA, with access to buyers across the Southern African Power Pool,” says Lion Mashiri, Managing Director for Zimbabwe at Africa GreenCo.
The design places 228MW of generation assets behind a 100MW grid connection, which allows for high utilisation of the grid infrastructure. The battery system is intended to smooth the variability between daytime solar output and night time wind generation, offering a model for managing intermittent renewable energy across the region.
Africa GreenCo’s role is seen as important to the project’s structure. As a creditworthy intermediary and a SAPP member, it can trade surplus power across borders, which reduces default risk and helps attract international investors.
The plant is also expected to ease Zimbabwe’s chronic power shortages, reducing reliance on electricity imports from neighbouring countries and on fossil fuel generation.
Author: Bryan Groenendaal







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“This isn’t a tiny home or a basic weekend shack.”
Photo Credit: iStock
An Australian homeowner with a large off-grid house can light, heat, and cool his home while running multiple appliances without a grid connection.
He puts the cost of electricity for his sprawling rural house at just 13 cents per kilowatt-hour.
Solar generation and battery storage are central to homeowner Martin Jacobson’s 5,382-square-foot (500-square-meter) home, but the house also relies on other energy sources.
North of Benalla, Victoria, Jacobson’s property draws on 20 kilowatt-hours of lithium battery storage and a 15-kilowatt solar array. He described the setup during a home tour on Farm Learning with Tim Thompson.
The house has a full-size kitchen, multiple refrigerators, and other everyday appliances that remain in use more than two years into off-grid living.
“This isn’t a tiny home or a basic weekend shack,” the channel’s caption noted.
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Jacobson’s estimated electricity cost is a personal calculation. As he explained in the video, it accounts for both his upfront spending and the cost of replacing the equipment after an assumed 12 years.
Having energy left in the batteries didn’t mean the system could power every appliance at once. Running the dishwasher, water pump, and electric kettle together could exceed the original 5-kilowatt inverter’s capacity, so Jacobson replaced it with a 10-kilowatt model. Still, he has zoned his home heating system and can switch it on and off independently to help reduce electrical load.
Short, cloudy days have sometimes left Jacobson relying on instantaneous gas hot water because his system couldn’t provide enough heat. His 132-gallon (500-liter) hot-water storage unit can also store energy. It takes surplus solar electricity once the batteries are full and stores it as heat.
Wood heating and air circulation kept living spaces comfortable during the mild winter discussed in the video, leaving the underfloor system unused. The underfloor heating has struggled to warm the whole house, although its 12 independently controlled zones allow Jacobson to leave unused rooms unheated.
“I certainly admire the amount of thought and effort Martin has put into his set up,” one commenter on the Farm Learning with Tim Thompson video wrote.
Seasonal usage patterns should guide capacity decisions, Jacobson advised homeowners considering a similar system. He recommended examining two or three years of electricity bills before deciding how much capacity they need.
For his own property, he would prefer 30 to 35 kilowatt-hours of battery storage and is adding roughly 4 kilowatts of solar panels.
For homeowners exploring solar without necessarily disconnecting from the grid, EasyHome can help them curate competitive bids from local installers.
Two water-heating additions are still being installed, but their results in Jacobson’s setup have yet to be demonstrated. A heat exchanger fitted to the wood heater’s flue and evacuated-tube solar water-heating equipment are intended to reduce his reliance on electric water heating.
Smaller adjustments are already helping him manage electricity use. His dishwasher runs on a midmorning timer and uses less than 2.9 gallons (11 liters) per wash, while low-energy DC ceiling fans circulate heat. He also schedules air-fryer cooking for sunny periods or when the batteries are full.
Jacobson’s approach includes LPG cooking and wood heating, so his off-grid electricity setup isn’t an all-electric home.
For everyday appliance use, Jacobson said: “You don’t have to be super careful with your power, but you’ve just got to be smart about how you use things.”
These stories cover solar and battery quotes, rebate deadlines, retirement planning, payback estimates, and inverter capacity.
• In Australia, a 6.6-kilowatt solar setup with 20-kilowatt-hour storage drew quotes from $8,000 to $20,000.
• An Australian family weighed a $6,000 solar-and-battery purchase ahead of Victoria’s rebate deadline.
• An Australian homeowner considers solar, batteries, and an EV as part of early-retirement plans.
• An Australian homeowner questioned whether a $19,800 solar quote could deliver five-year payback.
• A Queensland homeowner considering ALDI’s $10,999 solar deal learned why inverter size matters.
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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TYAGARAH, Australia, Nov. 3, 2026 /PRNewswire/ — Sungrow, the leading global PV inverter and energy storage system provider, partnered with ReSolve Global, a solar panel recycling facility in the Northern Rivers, supporting the next stage of Australia’s clean energy transition.
As Australia’s rooftop solar uptake continues to grow, so does the number of panels reaching the end of their working lives. The NSW Government recently announced consultation on Australia’s first mandatory solar panel product stewardship scheme, aimed at ensuring end-of-life panels are recovered, reused and recycled. Local infrastructure that can handle this equipment will be essential as the scheme develops.
ReSolve Global has established a 2,000-square-metre holding and sorting facility where used solar panels are collected, recorded, assessed and sorted.  It keeps used solar panels and other renewable-energy equipment out of landfill and recovers valuable materials for reuse and recycling.
“Solar has delivered enormous benefits for Australian homes and businesses, but we also need to take responsibility for the equipment coming off rooftops. Our goal is to build a transparent and practical system that prioritises reuse wherever appropriate and ensures the remaining materials are responsibly recovered.” Said Ben Pietzsch, Director of ReSolve Global.
To support the operation, Sungrow has sponsored a 20kWh SBH battery and 10kW SH10RS inverter, allowing the facility to run on clean, self-generated energy. The Sungrow SBH system pairs a hybrid energy storage solution with intelligent energy management, allowing the facility to store surplus solar generation and use it when needed. Combined with a Sungrow single-phase inverter, the system converts solar energy into reliable power for the facility’s daily operations, including equipment, lighting, and administration. This reduces reliance on grid electricity, lowers operating costs, and cuts emissions associated with the recycling process.
For Sungrow, supporting ReSolve is about closing the loop on the clean energy transition. A facility dedicated to recovering solar equipment should itself run on solar, demonstrating the circular, low-carbon model the industry is working towards.
“Solar has transformed how Australian homes and businesses generate power, and it’s our responsibility as an industry to make sure that equipment is managed well at the end of its life. ReSolve is doing exactly that, and we’re proud to support them. By powering their Tyagarah facility with a Sungrow SBH system and inverter, we’re helping ReSolve practise what it preaches: a recycling operation running on clean energy. It’s a meaningful step towards a truly circular solar industry, and we hope it inspires other businesses to follow.” said Richard Chen, C&I Business Development Manager of Sungrow.
The sponsorship reflects a shared commitment to sustainability. Sungrow contributes proven technology and more than two decades of expertise in PV and energy storage, while ReSolve brings local knowledge, hands-on recovery capability and a clear vision for reuse. Together, this demonstrates how manufacturers and recovery specialists can work side by side to support the full life cycle of solar.
“The Northern Rivers has long been a place where people are prepared to think differently about sustainability and resource use. It is fantastic to see that innovation happening locally and creating the potential for new skills, jobs and circular-economy opportunities in our region.” Tamara Smith MP of Ballina.
Looking ahead, Sungrow will continue to support ReSolve as it grows and to work with the wider industry to advance sustainable end-of-life solutions.
 
** This press release is distributed by PR Newswire through automated distribution system, for which the client assumes full responsibility. **
Closing the Loop: Sungrow Sponsors Solar and Storage System to Power Northern Rivers Solar Recycling Hub
SINGAPORE, Nov. 4, 2026 /PRNewswire/ — As AI adoption accelerates across Singapore, TechTIQ Solutions, a Singapore-based software development company, highlights a growing business challenge: integrating AI into mobile applications, enterprise systems, and everyday operations.
The company believes the next stage of digital transformation will depend not simply on adopting AI, but on connecting it with the software and data businesses rely on.
Singapore’s AI Growth Brings Integration into Focus
Singapore’s digital economy reached S$144.1 billion in 2025, contributing 19.3% of GDP, according to the Singapore Digital Economy Report released by the Infocomm Media Development Authority (IMDA) in October 2026.
AI adoption among small and medium-sized enterprises (SMEs) rose from 14.5% in 2024 to 23.4% in 2025. Yet only 28.3% of AI-adopting enterprises customized AI solutions to meet specific business requirements.
These figures highlight an opportunity to move beyond general-purpose AI tools toward tailored applications integrated with business operations.
From Mobile Apps to Connected Business Operations
For businesses investing in mobile app development, AI integration offers opportunities beyond customer-facing features.
A retail chain, for example, could connect bookings, loyalty programmes, inventory, and customer support through a unified mobile platform. AI could then automate enquiries, personalize recommendations, and generate operational insights.
Similar approaches can support healthcare, logistics, and financial services. However, successful implementation requires reliable data integration, system interoperability, security, and scalable architecture rather than simply adding AI features.
TechTIQ Solutions Focuses on Practical AI Integration
TechTIQ Solutions approaches AI-powered mobile app development as part of a broader engineering strategy, connecting mobile experiences with business processes and existing infrastructure.
Its services include custom mobile and web development, AI integration, API connectivity, cloud solutions, and enterprise software modernization.
“Adding AI features to a mobile application is only one part of the process. The real engineering challenge is making AI work reliably with a company’s existing data, systems, and operations,” said Thanh (Bruce) Pham, Co-founder of TechTIQ Solutions.
“Businesses should evaluate AI investments based on the problems they solve, the workflows they improve, and the value they deliver.”
Singapore Accountability, Vietnam Engineering Excellence
Vietnam’s digital technology industry generated an estimated US$198 billion in revenue in 2025, growing 26% year-on-year, according to its Ministry of Science and Technology.
TechTIQ Solutions combines Singapore-based contracting, project management, and quality assurance with Vietnam’s engineering capabilities, supported by a strategic investment from Saigon Technology. Recognized in the Vietnam Top 10 Tech & Map 2025 awards, Saigon Technology brings established software engineering expertise to this partnership.
This model offers Singapore businesses an end-to-end development approach combining local accountability, cost-competitive engineering, and structured delivery timelines.
Singapore’s AI Ambitions Demand Faster Execution
Singapore’s AI ambitions require more than technology adoption. Businesses need reliable solutions delivered within defined timelines and integrated into existing operations.
Through its Singapore-Vietnam engineering model, TechTIQ Solutions aims to combine international-standard software development, scalable delivery, and cost efficiency without compromising quality.
For Singapore businesses, the next competitive advantage will not come from adopting AI first, but from turning AI ambition into operational results faster.
About TechTIQ Solutions
TechTIQ Solutions is a Singapore-based software development company specializing in mobile app development, custom software, AI integration, and digital transformation. With Singapore-based project oversight, engineering capabilities in Vietnam, and a strategic investment from Saigon Technology, the company provides scalable, cost-efficient technology solutions for businesses across multiple industries.
 
** This press release is distributed by PR Newswire through automated distribution system, for which the client assumes full responsibility. **
TechTIQ Solutions Highlights Singapore’s Shift Toward AI-Integrated Mobile Apps
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Utility-scale solar developers are increasingly co-locating battery storage with new solar photovoltaic capacity. As of September 2026, over 16% of new utility-scale solar capacity added this year is co-located with operable battery storage, compared with 2% in 2017, according to data reported to EIA by operators.
Reported plans for solar additions scheduled to come online in the last three months of this year show that the share with co-located battery storage could increase to 19% this year. Longer-term plans indicate that this trend will continue, with the portion increasing to more than 30% in plans submitted for 2027 and 2028.
When operators co-locate battery storage with solar, they can direct solar electricity output to the grid or to the battery, depending on the wholesale prices. Wholesale prices in regions with large solar participation tend to fall when solar contributions are high and rise as they decrease. Plants with both solar and battery storage can manage the combined output of their generating resources to maximize their value in a changing wholesale price environment.
We publish unit-level generator inventory data based on our annual and monthly data collections, including information on design attributes for all utility-scale plants. Although battery storage and solar units at the same plant often enter commercial service at different times, the EIA-860 and EIA-860M data collection program tracks these developments and provides a monthly summary that can be used to identify co-located technologies.
Southwest states have higher-than-average solar capacity shares relative to their total generating capacity and also have higher levels of co-located utility-scale solar and battery capacity. As of September, 13% of the total U.S. utility-scale generating capacity is solar photovoltaic, and 18% of that is co-located with battery storage. The share of solar generation co-located with battery capacity in California, Arizona, New Mexico, and Nevada is more than double the national average.

Principal contributors: Glenn McGrath, Alex Mey
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New data from global energy consultancy Rystad Energy shows that all Australian large-scale solar power plants generated 5,100 GWh of clean energy last month, down 2% on the 5,200 GWh produced in October 2025 with Western Australia home to two of the top three best-performing utility PV assets for the month.
The 100 MW Merredin Solar Farm, owned Indonesian PV developer Sun Energy, was ranked Australia’s top-performing big PV facility for the month with Rystad Senior Analyst David Dixon noting the power plant had delivered an average AC capacity factor (CF) of 35% for the month.
Spanish energy giant Naturgy’s 128 MW Cunderdin Solar Farm ranked second for the month with the Western Australian facility delivering an average capacity factor of 32%.
Pacific Partnerships’ 102 MW Glenrowan Solar Farm in Victoria was ranked third with a capacity factor of 32% while stages one and two of Acen Australia’s 400 MW Stubbo solar project in New South Wales (NSW) were ranked fourth and fifth respectively.
Dixon said all Australian utility-scale PV and wind assets generated 5.1 TWh of clean energy last month, a 2% decrease on the 5.2 TWh generated in October 2025.
At a state level, Victoria was the biggest single contributor to the month’s total, generating 290 GWh from utility-scale solar and 1,130 GWh from wind – a total of 1,420 GWh.
The top wind assets for the month were the Flat Rocks (48% CF) and Warradarge (47% CF) wind farms in Western Australia, with the Clarke Creek stage 1b (44% CF) wind farm in Queensland third.
Dixon highlighted that on a trailing 12-month basis, the number of hours of negative prices and curtailed utility solar and wind generation are both beginning to decline as utility battery capacity comes online.
He said this trend is expected to continue over the next 24 months as the National Electricity Market (NEM) utility battery fleet grows from the current 26 GWh to almost 60 GWh by end 2028.
Dixon also noted that gas generation for October totalled 426 GWh in the National Electricity Market (NEM), the lowest for the month of October since the NEM began.
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