The Australian arm of Japanese energy company Idemitsu Kosan is proposing to develop a grid-scale vanadium flow battery as part of a clean energy precinct being advanced at a former coal mine in Muswellbrook, New South Wales.
The flow battery project, planned for the 2022-decommissioned Muswellbrook Coal Mine, will have a storage capacity of at least 108 MW/864 MWh, with up to 200 MW of bidirectional inverter capacity installed to allow for the battery energy storage system to charge or discharge for shorter periods of time where market conditions allow. The project will connect to the grid via Ausgrid’s 132 kV Sandy Creek substation.
Idemitsu said the project will use vanadium redox flow battery technology, noting it offers several advantages over lithium-ion batteries, including “use of a safe and stable non-flammable electrolyte, negligible battery degradation over 30 years, and flexible storage duration with potential to increase capacity by adding electrolyte to extend storage time.”
“Vanadium redox flow batteries are an Australian invention, born at the UNSW in 1984, that provide safe, true long-duration storage that is 99% reusable or recyclable at the end of 30 plus years of project life,” the company said.
Idemitsu said the use of vanadium flow technology represents a “catalyst project” that will support Australian manufacturing and demonstrate the technology’s readiness for the broader market adoption. It added that vanadium electrolyte used in the battery will be manufactured in Australia, and opportunities to bring battery manufacturing to Australia will be explored.
While the project is in early stage development, Idemitsu expects construction of the project to begin in early 2028 with the build phase to take about two years.
The vanadium flow battery project forms part of Idemitsu’s plan to repurpose the Muswellbrook coal mine site into a renewable energy precinct that will incorporate solar and pumped hydro, while investigations are continuing into developing green hydrogen facilities on-site.
Idemitsu is working with Swedish renewable energy developer OX2 which has commenced construction of a 135 MW solar farm and 135 MW/270 MWh battery project at the site. It is also collaborating with energy generator and retailer AGL to build a 400 MW pumped hydro project that would also use the mine site and would provide up to eight hours of energy storage.
Idemitsu said the Muswellbrook Clean Industries Precinct demonstrates how legacy mining assets can be repurposed to support long-duration energy storage, regional jobs and future industry.
From ESS News
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GAIL (India) Ltd. has invited bids for setting up a 600 MW solar PV project coupled with a 275 MW/550 MWh Battery Energy Storage System (BESS) in Jhansi, Uttar Pradesh. Bid submission ends on August 20, 2026.
July 24, 2026. By Mrinmoy Dey
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Brookfield Asset Management plans to buy solar and energy storage developer Aypa Power from Blackstone for approximately $7 billion. The investment will value Aypa at $3 billion.
Aypa has 12 projects (2.1 GW) under development in the United States, according to Cleanview. The company is working on solar and BESS projects in eight states, including Louisiana, Texas and California.
Under the terms of the agreement, Brookfield will acquire Aypa’s operating, under-construction and contracted project portfolio, together with its development platform and approximately 200-person team.
Aypa claims it has one of the largest standalone battery platforms in North America, comprised of 6.5 GW of operating, under-construction and contracted battery projects across the United States and Canada, with another 20 GW in the development pipeline.
Brookfield will partner with Aypa to accelerate the development of its pipeline by leveraging its operating and development expertise, access to capital and global supplier and commercial relationships.
“We are excited to partner with Aypa to deliver on the company’s scale growth pipeline,” said Jehangir Vevaina, Chief Investment Officer in Brookfield’s energy group. “Battery storage is increasingly critical to the reliability and resilience of today’s energy systems, and bringing together this leading platform with Brookfield’s broad capabilities across technologies and geographies further strengthens our ability to deliver integrated energy solutions to the world’s largest buyers of power.”
Moe Hajabed, Founder and Chief Executive Officer of Aypa Power, said: “This is an extraordinary achievement for the team that built Aypa. Over the past six years, with Blackstone’s partnership, we grew Aypa into the largest and most valuable storage-focused independent power producer in North America. Together, we helped establish battery storage as critical infrastructure, essential to a more reliable and resilient grid. I look forward to seeing Aypa flourish further under Brookfield’s ownership.”
Brookfield has also invested in the utility-scale businesses of Deriva Energy (formerly Duke Energy Renewables), Scout Clean Energy and Standard Solar.
Kelly Pickerel has more than 15 years of experience reporting on the U.S. solar industry and is currently editor in chief of Solar Power World. Email Kelly.
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The modular microinverter targets smaller U.S. solar installations while local electrical and utility rules still apply.
Hoymiles HiFlow Pro is bringing a UL 3700-compliant plug-in solar microinverter to the U.S., according to the company’s official product announcement. The system targets balconies, patios, and other spaces where a full rooftop installation may not fit.
A microinverter converts a solar panel’s DC output into household AC power. HiFlow Pro sends that energy into a compatible home circuit through a plug-in connection. Local rules still determine where and how owners can use it.
UL Solutions introduced UL 3700 as a dedicated safety framework for interactive plug-in photovoltaic systems. The standards organization says it covers construction, performance, labeling, safe installation, overload protection, and wrong-direction current flow.
The standard addresses exposed electrical parts and power flowing back toward utility lines. Anti-islanding protection matters because a solar system must stop energizing a circuit during a grid outage. That current could endanger utility workers.
UL 3700 does not turn every outdoor outlet into a solar connection. The standard’s scope calls for a permanently installed plug-in PV receptacle. It expects circuit components identified for bidirectional current flow.
Therefore, buyers need to check state law, local codes, utility policy, and the intended circuit before installation. Hoymiles warns against power strips and extension cords. The company says the system is not backup power because it shuts down when the grid fails.
Hoymiles offers HiFlow Pro models from 360W to 500W. Up to four microinverters can operate in parallel on separate sockets, reaching 1,200W total output where regulations permit. Meanwhile, the enclosure carries NEMA Type 6 and IP67 ratings for demanding indoor or outdoor conditions.
The company claims 99.8% static MPPT efficiency and 99.5% dynamic MPPT efficiency. It lists an operating range from -40 degrees Celsius to 65 degrees Celsius. Those figures come from Hoymiles, so real output will depend on panels, shade, weather, orientation, and the electrical setup.
Additionally, Bluetooth and Wi-Fi handle commissioning and monitoring through the S-Miles Home app. Hoymiles says initial pairing can take less than 60 seconds. A compatible energy meter can support zero-export control, although installation and configuration affect the result.
Plug-in solar occupies a different lane from whole-home rooftop systems. It differs from standalone solar gadgets, such as the solar security cameras Tech My Money recently covered. HiFlow Pro feeds usable energy into a home’s electrical system during normal grid operation.
Meanwhile, software is becoming a larger part of residential energy. For example, Jackery is adding AI management to home solar hardware. Hoymiles focuses instead on a smaller, modular entry point with app visibility and standardized safety features.
Ultimately, the HiFlow Pro launch removes one product hurdle, not every legal or electrical barrier. The hardware may make small-scale solar more practical for renters and homeowners. Yet its value depends on local permission, a suitable circuit, available sunlight, and daytime electricity use.
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Solar Energy
In 2017, Tesla presented a bold promise for the residential energy market: to transform the roof itself into a solar generation system, without relying on traditional solar panels installed over the roof. The idea was simple in speech, but extremely complex in practice.
Instead of placing solar modules over common tiles, the Tesla Solar Roof would replace part of the roof with tiles capable of generating electricity. Visually, the solar pieces were supposed to blend with the non-solar tiles, creating a more integrated cover with the house design.
At the time, CNN Money reported that Tesla estimated a cost of US$ 21.85 per square foot for the typical homeowner. Adapting for a simpler reading in Brazil, this is equivalent to US$ 21.85 for each square of about 30 cm by 30 cm of roof. A square foot measures 0.3048 m by 0.3048 m, or approximately 30.48 cm by 30.48 cm.
Few remember, but to transport children from an island in Pará to school, Brazilian universities built a solar boat that can carry up to 22 people, has a photovoltaic roof, two electric motors, and five hours of nighttime autonomy.
Solar panels installed in homes can provide energy to charge electric cars and reduce the monthly bill, combining energy efficiency, cost reduction, and a financial return that surprises many consumers.
More than 1,000 residents of a remote island in Kiribati now have clean water and electricity with solar systems operated by the community itself.
Island in Brazil Innovates by Installing 184 Solar Panels on Urban Lagoon to Generate Clean Energy
The Solar Roof was born as a visual and structural alternative to traditional solar panels. The logic was to replace the common roof with a cover made of glass solar tiles and metallic tiles without energy generation. The solar pieces would capture sunlight; the others would complete the roof without making the difference evident.
According to Tesla itself, the Solar Roof combines glass solar tiles and architectural steel tiles. The glass tiles produce energy, while the steel ones help with protection and durability of the cover.
This was the big differential. While solar panels are visible on the roof, the Solar Roof tried to transform the roof itself into an energy generator. It was an energy solution embedded in the construction, not just equipment installed afterward.
The most important number of the initial promise needs to be explained precisely. The value of US$ 21.85 was not the price of an individual tile. It was also not the cost per square meter.
It was an estimate per square foot, a unit of area used in the United States. In Brazil, the simplest way to translate this is to say that the value was equivalent to US$ 21.85 for a square of approximately 30 cm by 30 cm of roofing.
Converted to square meter, this same value amounts to about US$ 235 per m², because 1 m² has 10.7639 square feet. The calculation is straightforward: 21.85 × 10.7639 = US$ 235.19 per square meter.
Tesla did not design the Solar Roof for all tiles to be solar. According to CNN Money coverage in 2017, the tiles of a Solar Roof looked similar, but only some of them captured energy from the sun.
At that time, Elon Musk estimated that most homes would need about 40% coverage with active solar cells, while the rest would be filled with non-electric generating tiles.
This point was central to controlling the cost. If every piece of the roof were solar, the price could be even higher. By mixing active and non-active tiles, Tesla tried to balance appearance, energy generation, and budget.
In practice, the product functioned as a hybrid roof: part of the coverage produced electricity, part just protected the house and maintained a uniform look.
Tesla still presents the Solar Roof on its official website as a residential energy solution. On the current product page, the company states that the Solar Roof can be combined with the Powerwall, a home battery that stores the energy produced for use at night or during power outages.
Tesla itself also informs in its frequently asked questions section that it offers two solar solutions: Tesla Solar Panels and Solar Roof.
The company describes the Solar Roof as a covering that combines solar and non-solar tiles, while the solar panels appear as an alternative for those who do not intend to replace the roof.
In other words, the Solar Roof has not disappeared. The problem is that it did not become the popular and disruptive product that many imagined at launch. Instead of dominating residential roofs, it ended up becoming a more limited, more expensive solution that is more dependent on the specific conditions of each house.
One of the biggest obstacles of the Solar Roof was the installation. Traditional solar panels are installed over an existing structure.
The Solar Roof, on the other hand, involves replacing the roof, roof analysis, electrical adaptation, tile installation, connection with inverters, and integration with the battery.
Tesla itself states that the price of the Solar Roof depends on the total roof area, the number of solar tiles, the number of Powerwalls, and the complexity of the installation.
The company also claims that the final price is only determined after the final project, considering roof dimensions, electrical system, local permits, and utility requirements.
Each roof has different slopes, sizes, cutouts, chimneys, ventilation, structure, age, and conditions. This makes the Solar Roof much more difficult to standardize than a conventional solar panel.
Tesla currently states that if the project requires changes after the evaluation, a new price sheet may be sent to the customer for review and signature.
The product relied on an initial estimate, but the reality of the roof could change the final cost. A simple, wide roof with few obstacles tends to be very different from a roof full of cutouts, shadows, old structures, or additional electrical needs.
For this reason, the Solar Roof became an emblematic case of a technological promise that seemed simple on stage but encountered tough barriers in the field.
The most delicate moment came in 2021. According to Investopedia, Tesla agreed to pay US$ 6 million to settle a class action lawsuit related to the Solar Roof.
The report states that the lawsuit alleged price increases in 2021 and that about 8,636 customers were affected by the hikes.
The same report mentions that one of the allegations involved a customer whose price allegedly rose from US$ 72,000 to US$ 146,000 after the contract.
The case illustrates the main problem of the product: the gap between the initial budget, the actual installation cost, and the practical complexity of replacing an entire roof with an integrated solar system.
The difficulty was not limited to customers. According to Investopedia, Elon Musk stated in a first-quarter 2021 earnings call that the company had made significant errors in assessing how much the Solar Roof should cost.
According to the report, Musk explained that some roofs could be two or three times easier than others.
In cases with many protrusions or compromised structure, the cost could double or even triple compared to initial estimates.
The Solar Roof is not just a mass-produced piece. It depends on construction engineering, specialized labor, house conditions, local regulations, electrical connection, and utility authorization.
The biggest competitor of the Solar Roof has always been the traditional solar panel. Solar panels do not necessarily require replacing the entire roof. They can be installed over the existing covering, as long as the structure is adequate.
Tesla itself acknowledges this difference on its FAQ page. The company states that the Solar Roof is recommended for those updating the roof, while Tesla Solar Panels are an alternative for those not intending to replace the covering.
If a house already has a roof in good condition, installing panels can be simpler than tearing off the entire covering to install solar tiles. The Solar Roof makes more sense when the consumer also needs to replace the roof.
The Solar Roof had a very strong visual appeal. The idea of generating energy without visible panels seemed perfect for consumers concerned with design, facades, and property value.
But the solar energy market is usually highly sensitive to the cost per installed watt, the return time, and the ease of installation.
If traditional panels become cheaper, more available, and easier to install, the aesthetic advantage of the Solar Roof needs to justify a significant price difference.
This was one of Tesla’s great challenges. The product was technically interesting but needed to compete with an already established technology, manufactured on a global scale and installed by thousands of companies.
The Solar Roof cannot be treated as vaporware. It exists, has been installed in homes, and remains listed by Tesla as an energy solution.
The company states that the system uses glass solar tiles, architectural steel tiles, Powerwall, and monitoring via the Tesla app.
The promise in 2017 was to transform roofs into an elegant alternative to traditional solar panels. What happened next was more complicated: unpredictable costs, lengthy installations, price changes, dependency on the complexity of each roof, and a smaller potential audience than imagined.
The short answer is: Tesla’s solar tile didn’t end, but it got stuck between a brilliant promise and a difficult execution.
The product is still sold as a residential energy solution in the United States, but its use is more restricted than the original idea suggested.
The price of US$ 21.85 per 30 cm by 30 cm square of roof helped create an impact in 2017, but later experience showed that the real cost depended on many factors, especially the complexity of the roof.
Tesla wanted to create an alternative to traditional solar panels. It managed to create a visually different, technologically ambitious product integrated with the Powerwall battery.
But turning this idea into a cheap, simple, and mass-produced solution proved much more difficult than installing common solar panels on an already existing roof.
Graduated in Journalism and Marketing, he is the author of over 20,000 articles that have reached millions of readers in Brazil and abroad. He has written for brands and media outlets such as 99, Natura, O Boticário, CPG – Click Petróleo e Gás, Agência Raccon, among others. A specialist in the Automotive Industry, Technology, Careers (employability and courses), Economy, and other topics. For contact and editorial suggestions: valdemarmedeiros4@gmail.com. We do not accept resumes!
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The project aims to expand the existing Mokoan Solar Farm by adding a Battery Energy Storage System to the Victoria-based site.
Australian law firm Gilbert + Tobin has advised the Sydney branch of Deutsche Bank AG on the financing of the European Energy-sponsored Mokoan hybrid solar and battery project. The project reached its financial close on 8 July.
The Gilbert + Tobin advisory team was led by energy, resources and infrastructure partner Jamie Guthrie, with the wider team including partner Matthew Charman, lawyers Alex Bird and Jason Yu, and graduate Marshall Heller. The team provided guidance on all aspects of the refinancing, project financing and battery development.
The Mokoan Solar Farm is located in Victoria, and has been fully operational for over a year, since June 2025. The 58MW farm generates approximately 113GWh in electricity per year, the equivalent needed to power around 18,000 homes. The Mokoan Battery Energy Storage System (BESS) is set to occupy the same location as the Solar farm, and, once operational, the 40MW/80MWh BESS will further expand Australia’s renewable energy potential as well as supporting the stabilisation of its energy grid.
Under the terms of the financing, Deutsche Bank, serving as sole lender and letter of credit facility financier, has provided an AU$ 110 million, three-year non-recourse financing package, which will refinance existing debt facilities as well as facilitating the construction and operation of the BESS project. Deutsche Bank also acted as hedging bank for the interest rate swap solution and as account bank, facility agent and security trustee for the transaction.
Amazon Australia and a government-backed support mechanism through the Capacity Investment Scheme (CIS) are also providing support to the project via long-term solar and battery offtake arrangements.
Gilbert + Tobin’s Guthrie commented: “Mokoan is a strong example of how established solar assets can be enhanced with battery storage to optimise and reshape the facilities’ generation profile against the backdrop of an increasingly competitive and challenging market. The financing required careful structuring across the solar refinancing, battery development and integration, long-term offtake arrangements and CIS support. We are pleased to have advised Deutsche Bank on a transaction that demonstrates the continued evolution of Australia’s renewable energy financing market and the increasing bankability of hybrid generation and storage projects.”
Deutsche Bank’s head of project finance, APAC Rachel Chia remarked: “We are proud to support projects that enable greater renewable energy integration and contribute to Australia’s energy transition. This transaction demonstrates our ability to deliver integrated financing solutions across the project lifecycle, supporting clients as they develop critical energy infrastructure.”
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Jupiter’s cumulative solar cell manufacturing capacity has increased to 4.5GW.
Jupiter International’s joint venture with renewable energy company Ampin Energy Transition has produced its first solar cell, marking the start of operations at their integrated manufacturing facility in Odisha, India.
The facility, operated by Ampin Solar One, was inaugurated in Bhubaneswar in April and manufactures both solar cells and modules.
With the new production line online, Jupiter’s cumulative solar cell manufacturing capacity has increased to 4.5 gigawatts, whilst its module manufacturing capacity stands at 1.5 GW, the company said.
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As India's solar manufacturing becomes more localized, its competitiveness in international markets will continue to improve
July 23, 2026
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The rush to comply with the Approved List of Models and Manufacturers (ALMM) guidelines for solar modules and cells has sparked concerns among industry stakeholders about a potential mismatch between demand and supply and delayed project timelines.
While module manufacturers are gearing up to increase production and meet demand, Kayan Kalthia, Director at Kosol Energie, feels the sector might face cell supply constraints for another six to seven months before new domestic capacity stabilizes the market.
In an interview on the sidelines of the Mercom India Renewables Summit 2026, held in New Delhi on July 1 and 2, Kalthia talks about India’s solar manufacturing ecosystem, export opportunities, timelines for the Approved List of Models and Manufacturers (ALMM), battery energy storage, and Kosol’s plans to foray into battery cell manufacturing.
The following are edited excerpts from the interview.
Given the wide gap between ALMM-listed module capacity and cell capacity, how much domestic cell capacity is currently available to independent module manufacturers?
Cell manufacturers are making every effort to increase supplies, but the number of module manufacturers far exceeds the available domestic cell capacity. Currently, only about 20% to 25% of India’s domestic cell production is available to independent module manufacturers, well below what the market requires.
The industry had anticipated this shortage and is prepared to deal with it. I expect the next six to seven months to remain challenging, but additional cell manufacturing capacity should come online and stabilize the market after that period.
Kosol has been in the industry since 2012, and our long-standing relationships with cell manufacturers have helped us secure supplies.
With more than 250 GW of module manufacturing capacity announced or under construction, where can this additional capacity be sold?
Selling that additional capacity will be difficult, regardless of the market. Europe continues to be largely dominated by Chinese manufacturers. In markets where non-Chinese sourcing requirements are emerging, there are more economical Southeast Asian suppliers than Indian manufacturers.
The industry needs to take a hard look at where it is allocating capital. It also needs to consider new ways of deploying this power. Data center capacity is expanding rapidly, and if grid connectivity becomes a constraint for these facilities, off-grid power systems could create another avenue for deploying additional module manufacturing capacity.
The U.S. was previously a significant market for Indian exporters. Do you see any other export markets emerging for Indian modules?
Even when India exported significant volumes to the U.S., exports were concentrated among a relatively small number of manufacturers. Most of those select exporters now have their own cell manufacturing capacity.
Alternative markets exist, but Indian manufacturers will continue to face strong competition from Chinese suppliers. The more indigenized Indian manufacturing becomes, the more competitive it can be internationally.
However, selling modules compliant with domestic content requirements in India is currently more viable than exporting them. Kosol continues to export because of its technological capabilities and advances in module technology, which help us maintain a competitive edge. I am unsure about how many recently established module manufacturers have approached the market with the same focus.
The industry faced bottlenecks when the ALMM lists I and II were introduced, and there is now a timeline for ingot and wafer manufacturing. Should the government reconsider these timelines?
I do not think the timelines should be reconsidered. By maintaining the deadlines, the government has demonstrated that it will not continue moving the goalposts. That provides investors with greater confidence and makes it easier to raise capital for further vertical integration.
Many cell manufacturing projects have been announced, and India may have to face an overcapacity phase. However, I believe that it could be beneficial for the sector because it may open export markets for Indian manufacturers.
An ingot and wafer manufacturing facility takes around two years to establish. Since the government is maintaining the implementation timeline, investors are more confident and willing to commit capital to these projects.
Which segments are most likely to drive energy storage demand: commercial and industrial (C&I), residential, or public utility projects?
Public utility projects will see the largest growth because their business case and project parameters are easier to define and evaluate.
However, the C&I segment could offer higher internal rates of return. India is moving toward time-of-day tariffs, with different tariffs during solar and non-solar hours. The wider that difference becomes, the more viable battery energy storage systems will be for commercial, industrial, and residential consumers.
In some developed markets, the tariff difference can be as high as six times. At that level, battery storage becomes highly attractive and almost mandatory.
India still depends heavily on China for battery cells. How do you see the battery value chain becoming more indigenous? What are the main bottlenecks?
I expect domestic battery cell manufacturing to develop quickly. The solar manufacturing experience has demonstrated that the Indian government supports indigenous manufacturing.
Kosol is actively moving toward battery cell manufacturing because we expect the government to continue supporting domestic production. Based on our experience in solar manufacturing, we also expect to have excess capacity that can serve other battery assembly companies entering the market.
Arjun Joshi
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China’s solar manufacturing output and new PV installations declined across all major supply chain segments during H1 2026, says CPIA
Despite the domestic slowdown, export value increased due to growing overseas manufacturing and demand from international markets
CPIA expects the global market to recover after a temporary slowdown, with policy support and solar-plus-storage driving long-term growth
China’s solar PV industry underwent a significant adjustment during H1 2026, with manufacturing output and domestic installations declining sharply even as exports continued to grow, according to a report released by the China Photovoltaic Industry Association (CPIA).
The report said output declined across all major segments of the PV supply chain. Between January and June 2026, China produced 538,000 metric tons of polysilicon, 293 GW of wafers, 260.7 GW of solar cells, and 201.3 GW of modules. Compared with the same period last year, polysilicon output fell by 9.8%, wafers by 7.3%, cells by 21.9%, and modules by 35.1%.
China installed 72.07 GW AC of new solar PV capacity during the six-month period, representing a 66% year-on-year (YoY) decline. However, CPIA’s Bohua Wang noted that installations remained above the average first-half level recorded between 2021 and 2024. Solar additions in H1 2025 totaled 197.85 GW AC, mainly due to over 92 GW AC installed in May to meet the June 1 deadline of FIT expiration (see China’s June 2025 Solar PV Additions Fall To 14.36 GW).
Despite weaker domestic demand, the country’s PV exports remained resilient. Total export value rose 24.3% YoY to $17.18 billion, supported by higher overseas demand for cells and wafers as solar manufacturing capacity expanded outside China.
Indonesia became the largest destination for Chinese cell exports, while India emerged as the biggest market for wafer exports. Europe continued to be a major destination for modules, with Southeast Asia and Africa also contributing to overseas demand.
The association also highlighted continued pressure on manufacturers as prices for polysilicon, wafers, and cells declined during the reporting period, while module prices increased slightly. Companies also faced weaker profitability, lower revenues, longer payment cycles, and reduced financing capacity.
On the policy front, CPIA said China continued to strengthen its PV manufacturing framework through measures focused on product quality, green manufacturing, and digitalization. New regulations also addressed module safety, energy efficiency, renewable electricity use, AI-enabled manufacturing, and industrial decarbonization.
At the same time, the report pointed to rising global trade barriers, including US tariffs and investigations, European sustainability regulations, and India’s import restrictions.
Looking ahead, CPIA reiterated its stance that global solar installations will experience a temporary slowdown in 2026 before returning to growth in 2027 and beyond. Under its medium-case scenario, the association forecasts around 612 GW DC of new PV installations worldwide in 2026, driven by the impact of Chinese policy, representing a YoY decline from around 664 GW DC installed in 2025. Growth will pick up after this temporary slowdown and annual installations will reach 864 GW by 2030.
It said long-term growth will be supported by China’s new energy system, greater focus on energy security, rising demand for green electricity, and improving competitiveness of solar-plus-storage projects.
Wind and solar are central to China’s renewable energy targets under the 15th Five-Year Plan, with a combined capacity of 2.8 TW AC by 2030 (see China Targets 2.8 TW AC Solar & Wind In 15th Five-Year Plan).
TaiyangNews 2024
China has released the full texts of three mandatory national standards that impose energy consumption and efficiency limits across the photovoltaic manufacturing value chain.
The standards were approved on June 27, published in full on July 22 and will take effect on Jan. 1, 2027. They cover polysilicon and germanium production, monocrystalline silicon manufacturing, and the efficiency of crystalline silicon modules and inverters.
The most significant changes appear in GB 29447-2026, the revised energy consumption standard for polysilicon and germanium production. The final version is stricter than the draft released for public consultation in September 2025.
For polysilicon produced through the trichlorosilane process, which is commonly used to produce rod silicon, the three energy consumption grades are set at 5.0, 5.5 and 6.3 kilograms of standard coal equivalent (kgce) per kilogram of product. The Grade 3 limit, which represents the maximum allowable energy consumption for existing production, has been tightened from 6.4 kgce/kg in the consultation draft.
For silane fluidized-bed production, used primarily to manufacture granular silicon, the Grade 1, Grade 2 and Grade 3 limits are 3.6, 4.0 and 4.6 kgce/kg, respectively. The final Grade 3 threshold is significantly lower than the proposed 5.0 kgce/kg.
The standard also tightens accounting rules for externally sourced silicon cores and hydrogen, reducing the scope for producers to lower reported energy consumption through differences in calculation boundaries.
The revisions exceeded earlier market expectations because much of China’s existing rod silicon capacity reportedly operates within a narrow range of 6.3 to 6.4 kgce/kg. An industry estimate cited after a standards implementation meeting suggested that around 84% of capacity could meet the draft 6.4 kgce/kg threshold, but only about 45% could comply with the final 6.3 kgce/kg limit.
The estimate is not an official assessment of production capacity and does not mean that all non-compliant facilities will immediately cease operations. Producers may improve performance through measures such as heat recovery, process optimization, higher operating rates or other technical upgrades.
Brokerage estimates nevertheless suggest that the standard could reduce China’s compliant polysilicon capacity from around 3.5 million tonnes to less than 2 million tonnes. That would remove more than 1.5 million tonnes from the compliant capacity pool, compared with estimated demand of about 1.5 million tonnes in 2027.
The immediate impact on supply may be more limited. Much of the higher-energy production capacity is already idle, while operating polysilicon capacity stood at around 1.3 million tonnes during the first half of 2026.
The other two standards extend the mandatory framework further downstream. GB 47835-2026 sets energy consumption limits for crystal pulling and wafer slicing, while GB 47834-2026 establishes minimum efficiency requirements for crystalline silicon modules and inverters. Products that fail to meet the Grade 3 requirements for modules and inverters will not be permitted to be manufactured, imported or sold in China.
Together, the new standards shift China’s campaign against PV overcapacity from voluntary production discipline toward binding technical regulation.
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County may have broken state law.
Springfield, IL (CAPITOL CITY NOW) – A week after being sued for saying Yes to a project, the Sangamon County Board is being sued for saying No to another one – a solar farm which would be located off Lenhart Road.
“Last week we talked about the group of residents that is suing to try to block the CyrusOne data center project, and now we have kind of the reveres situation,” says Springfield Business Journal executive editor Michelle Ownbey. “We’ve got a landowner and developer who are suing because their solar project was not approved. Just a year or so ago, the state had passed some legislation that essentially took away a lot of control from local municipalities. The whole idea is to attract more wind and solar developments and green energy and that kind of thing, and Gov. Pritzker was trying to give the developers a bit more certainty in attempting to woo them to come to Illinois, but that meant that local municipalities are not allowed to have stricter regulations than what was already outlined by the state.”
The Business Journal reports the developer is Summit Ridge Energy, and the landowner is Mark Roberts III.
Ownbey told the WTAX Morning Newswatch the board acted against the advice of its attorney and may have broken state law in denying the application.
A Sangamon County spokesperson has not responded to Capitol City Now’s request for comment.
CLICK HERE to read the 591 page lawsuit (PDF).
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County may have broken state law.
The identity of the victim is not known, but police say he is in “stable” condition.
The company will receive incentives through the state’s Manufacturing Illinois Chips for Real Opportunity, or MICRO, program.
Springfield, IL (CAPITOL CITY NOW) – As outdoor temperatures climb, it’s important to stay […]
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The new 755-foot-long vessel can transport 10,800 vehicles and will operate global shipping routes for Hyundai Glovis after its delivery to South Korea’s KOBC.
China on Tuesday delivered the world’s first 10,000-vehicle-class car carrier equipped with a photovoltaic power generation system to South Korea’s Korea Ocean Business Corporation (KOBC). Built by Guangzhou Shipyard International (GSI), the ship can carry up to 10,800 vehicles and uses both solar power and liquefied natural gas (LNG) dual-fuel engines to boost fuel efficiency and cut emissions worldwide.
The delivery took place through a remote online signing ceremony between GSI and China Shipbuilding Trading Co., Ltd., as KOBC chose a virtual handover instead of an in-person event. According to GSI, the new ship will be leased to Hyundai Glovis for international routes connecting Asia, Southeast Asia, North America, and Europe.
This new Pure Car and Truck Carrier (PCTC) is the fourth carrier of its size delivered by China, and it is the first in its class to have a solar power system.
The ship’s solar system can produce up to 200 kilowatts at its peak and generates about 1,000 kilowatt-hours of electricity daily with 5.5 to 7 hours of sunlight. This power helps run the ship’s operations, lowering fuel use and making the ship more energy efficient.
The carrier also uses a dual-fuel propulsion system that operates on conventional fuel oil and LNG. It includes a shaft generator and meets the International Maritime Organization’s Tier III emissions standards. According to GSI, this combination makes it the most energy-efficient vessel in its series.
GSI and the Shanghai Merchant Ship Design and Research Institute worked together to design the vessel. It has been approved by Norway’s Det Norske Veritas and South Korea’s Korean Register, so it can operate anywhere in the world.
The carrier is about 755 feet (230 meters) long, 131 feet (40 meters) wide, and has a draft of 34.4 feet (10.5 meters). It can travel at speeds up to 19 knots, which is about 22 mph (35 km/h).
The ship’s LNG tanks hold enough fuel for a full trip, so it does not need to refuel during long journeys.
The ship has 14 decks for vehicles, with nine fixed and five adjustable. This setup lets it carry passenger cars, vans, heavy trucks, trailers with freight containers, and other large vehicles.
In addition to cars, the ship can carry some packaged dangerous goods covered by the International Maritime Dangerous Goods (IMDG) Code. This expands the types of cargo it can transport.
This latest delivery adds to GSI’s growing lineup of large vehicle carriers and shows China’s increasing role in building new commercial ships.
When Hyundai Glovis starts using the ship, it will help move vehicles between major manufacturing and consumer markets in Asia, Southeast Asia, North America, and Europe. The use of solar power and LNG engines also shows the shipping industry’s wider push to cut emissions while still carrying large amounts of cargo.
A versatile writer, Sujita has worked with Mashable Middle East and News Daily 24. When she isn't writing, you can find her glued to the latest web series and movies.
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Centre for Science and Environment (CSE) is organising a three-day National Roundtable to discuss a roadmap for scaling up rooftop solar deployment across India. The roundtable is expected to bring together policymakers, DISCOMs, project developers, financiers, vendors and consumers to examine how rooftop solar can move from scattered, subsidy-driven pilots to a scaled, self-sustaining market across residential, commercial & industrial (C&I) and institutional consumers.
Unlocking rooftop solar’s full potential across every consumer segment is critical to meeting India’s 500-GW renewable energy target by 2030. PM Surya Ghar has brought residential rooftop solar into the mainstream, while the commercial and industrial segment is opening up in its own right, driven by net-metering reforms, RESCO models and green financing. Institutional buildings remain a large but still under-tapped opportunity. Several barriers continue to slow the pace of scale-up, however: delays in subsidy and CFA disbursement, inconsistent net-metering timelines, uneven vendor quality, financing gaps for public buildings, and low consumer awareness, particularly around post-installation maintenance and upkeep. This roundtable builds on CSE’s ongoing rooftop solar research to confront these barriers directly and chart pathways for programmatic, cross-segment scale-up.
KEY SESSIONS AND SUBJECTS OF DISCUSSION
FOR FURTHER DETAILS AND INFORMATION, PLEASE CONTACT
BINIT DAS
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+91 80933 26269
DIMITRI BARURY
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dimitri.barury@cseindia.org
+91 98107 78293
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Ark Energy, an Australia-based renewable energy company owned by Korea Zinc, has reached financial investment decision for the AUD 1.3 billion (~ $9.09 billion) Richmond Valley Solar Farm & BESS in New South Wales. Korea Zinc approved the decision in Seoul on July 21, 2026. The financing package comprises of AUD 586 million (~ $409.79 million) in equity and AUD 716 million in debt. The priority stage includes 200 MW AC solar farm and a 275 MW / 2,200 MWh LFP BESS. The project received NSW planning approval in October 2025, federal environmental approval in December 2025 and grid connection approval in June 2026. Financial close is targeted for September 2026, followed by construction from October 2026. Operations are scheduled for January 2029 while peak construction is expected to support more than 850 direct and indirect jobs.
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Eversource, National Grid, EnergyHub, Sunrun and The Mobility House announced a joint effort to test vehicle-to-grid (V2G) capabilities in Massachusetts.
Under this effort, qualifying residential customers of Eversource and National Grid in Massachusetts will be able to enroll their V2G-capable electric vehicles (EVs) in ConnectedSolutions. The existing ConnectedSolutions program uses flexible capacity from thermostats, batteries, and commercial and industrial resources to reduce grid strain, and Eversource and National Grid will be leveraging those capabilities to test how they apply to V2G.
“ConnectedSolutions is an important part of our strategy to deliver safe, reliable and affordable service,” said David Roman Ubeda, Senior Program Manager at National Grid. “V2G may provide additional opportunities to customers in support of managing their energy bills while advancing long-term sustainability across Massachusetts.”
With more than 150,000 EVs on the road and an increasing number of bidirectional-capable models available, Massachusetts is sitting on a large and growing energy reserve. The introduction of vehicle-to-grid capabilities enables drivers to give back to the grid, turning every parked EV into a vital tool for a more reliable energy system.
National Grid is also currently leveraging V2G for light-to-medium-duty fleets within ConnectedSolutions, beginning with school buses, while Eversource is in discussions with districts as part of its ConnectedSolutions+ offering.
“ConnectedSolutions is a nation-leading model for implementing virtual power plants, enabling us to actively partner with customers to help ease the strain on the electric grid,” said Tilak Subrahmanian, Eversource Vice President of Energy Efficiency and Electric Mobility. “We are proud of the impact our demand response efforts have had so far, and we are excited to test the capabilities we’ve built within ConnectedSolutions on new innovations, such as V2G.”
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Kelly Pickerel has more than 15 years of experience reporting on the U.S. solar industry and is currently editor in chief of Solar Power World. Email Kelly.
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• Zanzibar utilities regulatory agency visits to understudy Nigeria
•Aliyu: Nigeria must prepare for AI driven surge in electricity demand
Emmanuel Addeh in Abuja
The Rural Electrification Agency (REA) has reiterated the organisation’s commitment to the ambitious roadmap aimed at achieving universal electricity access in Nigeria by 2060 while developing 3.7 gigawatts of local renewable energy manufacturing capacity as part of efforts to deepen energy access and industrialisation.
Managing Director of the REA, Dr Abba Aliyu, disclosed this while presenting the agency’s electrification strategy to a visiting delegation from the Zanzibar Utilities Regulatory Authority (ZURA) in Abuja, saying Nigeria was accelerating investments in renewable energy to close its electricity access gap and position itself for the rapidly growing global demand for power.
The REA chief executive said agreements signed during the 2025 Nigeria Renewable Energy Innovation Forum would unlock a combined manufacturing capacity of 3.7 gigawatts across six states in partnership with seven companies.
The projects, he said, include photovoltaic manufacturing facilities in Kano, Abuja, Ogun, Bayelsa and Akwa Ibom states, alongside a recycling plant in Lagos.
“We are about to inject 3.7 gigawatts of manufacturing capacity in Nigeria. Already many of Nigeria’s PV panels produced in Lagos have been exported to Ghana.
“We want to reduce the importation of PV panels from China. We are asking Chinese companies to come to Nigeria and establish their factories. By the end of next year, we will have 3.7 gigawatts manufacturing capacity. This is one of the biggest achievements that we have recorded,” Aliyu said.
He attributed the falling cost of renewable energy technologies largely to advances in Chinese manufacturing, noting that declining prices for photovoltaic panels and lithium batteries were making renewable energy the most economically viable option for expanding electricity access.
“One of the reasons is credit goes to the Chinese. They have really demystified renewable energy technology. They have crashed the cost of PV panels. Even lithium battery pricing has gone down and will continue to go down,” he stated.
Aliyu argued that global electricity demand was entering an unprecedented phase driven by population growth, widespread electrification and the rapid expansion of artificial intelligence and data centres.
“The demand for electricity has never been seen before. There are three critical reasons: electrification of everything, population growth and AI and data centres. Electricity is going to determine how health services, education, agriculture and virtually everything else will be done,” he said.
He stressed that African countries must not only pursue universal electricity access but also prepare for the next wave of electricity demand arising from technological transformation.
The REA boss said the agency had developed one of the country’s most comprehensive geospatial databases, mapping more than 700,000 communities, over 51,000 hospitals, 11,000 markets, thousands of schools, factories, dams and electricity feeders to guide least cost electrification planning.
According to him, the mapping enables the agency to determine whether communities should be served through solar home systems, mini grids or grid extension based on technical and economic considerations rather than adopting a one size fits all approach.
Aliyu also disclosed that Nigeria now has several Renewable Energy Service Companies (RESCOs), many of which have evolved from contractors into utility scale operators and are already expanding into other African countries following reforms to the country’s mini grid regulations.
Aliyu reiterated that about 85 million Nigerians, representing almost 40 per cent of the population, still lacked access to electricity, despite the country’s electrification rate currently standing at about 61 per cent.
He noted that Nigeria’s average electricity demand is estimated at 25,000 megawatts, while peak available supply remains about 4,000 megawatts, underscoring the scale of the country’s energy deficit.
To support ongoing projects, Aliyu reiterated that the REA currently has a public finance and grants portfolio of about $1.23 billion sourced from federal budget appropriations, regulatory funding, development finance institutions, bilateral partners and intervention funds.
He listed major funding windows to include the Distributed Access through Renewable Energy Scale up (DARES) programme, the Renewed Hope Infrastructure Development Fund, the Nigeria Power Sector Support Initiative, and other intervention schemes.
Speaking during the visit, World Bank Consultant to the Zanzibar Electricity Corporation (ZURA), Dr. William Gboney, described Nigeria as one of Africa’s leading countries in off grid and mini grid regulation.
Gboney said the visit had demonstrated that African countries could increasingly learn from one another in developing sustainable electricity access solutions, underscoring the need for the visit.
“We don’t necessarily have to travel outside Africa to build capacity or acquire new knowledge. Based on my research, when it comes to off-grid and mini grid regulation, Nigeria ranks among the best on the continent,” he said.
Founded on January 22, 1995, THISDAY is published by THISDAY NEWSPAPERS LTD., 35 Creek Road Apapa, Lagos, Nigeria with offices in 36 states of Nigeria , the Federal Capital Territory and around the world. It is Nigeria’s most authoritative news media available on all platforms for the political, business, professional and diplomatic elite and broader middle classes while serving as the meeting point of new ideas, culture and technology for the aspirationals and millennials. The newspaper is a public trust dedicated to the pursuit of truth and reason covering a range of issues from breaking news to politics, business, the markets, the arts, sports and community to the crossroads of people and society.
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India ran into an obstacle in its ambitions to boost solar generation as local factories began to shut down because of component shortages, Reuters reported today, citing unnamed industry sources.
The shortages are the result of new legislation seeking to reduce India’s dependence on solar technology imports from China and are putting investments worth some $4 billion at risk, the sources said. Since June 1, when the new legislation took effect, close to a third of India’s small and medium solar module makers have shut shop. The small and medium segment of the industry makes up 60% of the total.
“We have suffered a lot due to the domestic cell unavailability for the past three months,” one solar panel maker said, as quoted by the publication. He expects production of solar modules to drop from 3.2 GW to just 1 GW as a result of the new legislation’s entry into effect.
The legislation in question mandates that India’s solar module makers only use domestically produced cells for solar panels. At the time, the industry warned the government that this would lead to higher module prices and slow down the rollout of solar capacity, because local cell manufacturing capacity is below demand, with the gap at some 2.6 GW annually. Imports from China accounted for over 90% of the cells used by Indian module makers before the new law came into effect.
India’s government has a target of 500 GW of non-hydrocarbon generation capacity by 2030 and the latest developments will likely interfere with that. Solar accounts for 29% of the country’s non-hydrocarbon generation capacity, Reuters noted in its report. Plans were to expand it from 162 GW currently to over 292 GW by 2030. This target is now under threat because while local module capacity is substantial, at 200 GW, solar cell manufacturing capacity is just 27 GW.
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India’s severe heatwaves in April and May, followed by a delayed southwest monsoon, have highlighted the growing challenge of balancing one of the world’s fastest-growing renewable power systems. As solar capacity continues to expand and grid constraints become more apparent, India’s battery energy storage sector is at a pivotal stage.
Low battery prices in the first three quarters of 2025 led to record low tariffs in standalone battery tenders in the range of INR 1.6-1.9 lakh/MW/month. However, increasing battery prices in recent months driven by tightening supply of raw materials and policy changes in China, still the world’s dominant battery manufacturer, have pushed standalone battery tender tariffs to around INR 2.1 lakh/MW/month, leaving some of the previously-tendered capacity at risk of delays or non-delivery.
Despite this volatility, there is broad consensus that batteries will play a critical role in India’s power sector.
This year’s delayed monsoon and heatwaves in April and May increased electricity demand, leading to consistent periods of power prices clearing at the INR 10/kWh price cap in the Day Ahead Market during the evening and overnight. On the other hand, extended periods of hot, dry weather across parts of India created favourable conditions for stronger solar generation, leading to low power prices around midday. The higher renewable output increases the risk of curtailment where transmission infrastructure and grid flexibility cannot keep pace.
The challenge is not new. In 2025, delays in the commissioning of transmission lines, record solar capacity additions of more than 38 GW and subdued power demand during an extended monsoon season resulted in more than 5 TWh of renewable generation being subject to T-GNA curtailment. Retrofitting batteries at solar sites can provide a hedge against such curtailment, allowing excess generation to be stored, while also creating opportunities to sell power in the evening when prices are higher.
The Central Electricity Authority of India (CEA)’s Generation Adequacy Plan of 2026-2036, estimates 147 GWh of battery storage to be required by 2031-32 and 321 GWh by 2035-36, to maintain reliability as renewable energy grows. Given the Indian power sector’s solar-heavy nature, batteries are uniquely positioned to charge up excess solar generation during the midday hours and discharge in the evening hours to meet demand when solar output falls.
This balancing role becomes important as coal capacity additions struggle to keep pace with the growth in peak demand. Unlike large thermal projects, batteries have short commissioning timelines and can be deployed quickly. Over time, as technology improves and costs fall further, India is likely to see a shift towards longer-duration storage, allowing batteries to cover extended periods of evening and night-time demand. Grid-forming batteries have also picked up globally in recent years, providing better voltage and frequency regulation in addition to load shifting capabilities.
Most battery storage projects in India have been contracted through tenders conducted by the Renewable Energy Implementing Agencies (REIAs) or Distribution Companies (DISCOMs). These range from relatively simple capacity-based tolling contracts to complex Firm and Dispatchable Renewable Energy (FDRE) tenders which require optimisation across renewables, storage, and market procurement to meet the power delivery requirements. These tenders have provided the revenue-certainty required to kick-start the market, with batteries forming a crucial component of FDRE project portfolios due to the strict non-delivery penalties.
The interest in batteries is also growing beyond the government tenders route. The Commercial and Industrial (C&I) sector has also seen an increase in interest in contracting battery capacity in recent months, driven by tightening electricity banking regulations in some states and mandatory storage capacity requirements. Maharashtra’s recent Renewable Energy and Energy Storage Policy mandated at least 2 hours of energy storage equivalent to 50% of project capacity for new projects.
Regulatory changes are also strengthening the case for battery storage. The tightening of deviation bands under the Deviation Settlement Mechanism from 1st April 2026 has increased the penalty risk for standalone solar and wind projects, leading to developers exploring the addition of battery storage on plants facing high penalties, or at a pooling substation to collectively manage deviations at a substation-level rather than at plant-level.
The merchant market for batteries in India remains nascent but offers an advantage compared to fully contracted models. Rising price volatility, driven by excess midday solar generation and strong evening demand, has widened arbitrage opportunities, with average one-hour price spreads increasing to INR 7.42/kWh in 2025 from INR 6.95/kWh in 2024. Events such as this year’s delayed southwest monsoon and severe heatwaves in April and May further demonstrate how weather-related shifts in supply and demand can create additional value for flexible storage.
This is already translating into real activity, with developers commissioning merchant battery projects and trading power on exchanges, such as Juniper Green’s 100MWh system. An important next step for the sector is the development of domestic battery manufacturing. India’s Production-Linked Incentive scheme has allocated 40 GWh of manufacturing capacity across two auctions but progress on the ground has been slower than hoped. Most battery projects being deployed in India today are using batteries imported from China, which has most of the global battery manufacturing capacity. Scaling up domestic manufacturing, first in cell-to-pack assembly and eventually in manufacturing cells, will be key to reducing costs, improving security of supply, and supporting long-term growth.
Globally, there is no single model for deploying battery storage. Some markets like the UK support batteries through capacity markets, others like Australia’s NEM rely on highly volatile energy and ancillary service markets, and still others, like India, are building systems based on long-term contracts which provide revenue certainty. What is clear is that batteries can be deployed under different frameworks, provided market design evolves alongside system needs, to provide batteries with the ability to stack various revenue streams together.
For India, this evolution is underway, but further reforms will strengthen the business case for battery storage. Despite high volatility in power exchange prices, the INR 10/kWh price cap in the Day-Ahead Market and Real Time Market limits revenue potential for batteries and constrains the growth of merchant models. Revising this cap would improve project economics and unlock greater private investment.
Batteries are also well suited to provide ancillary services such as frequency control due to their bidirectional and dispatchable nature, and quick response times. While Primary, Secondary, and Tertiary Reserve Ancillary Services exist in India, only the Tertiary Reserve is currently procured through the power exchanges. Expanding procurement across these services would create additional revenue streams and accelerate deployment.
Ultimately, the opportunity for battery storage in India is clear, but the pace of scale-up will depend on how quickly these market constraints are addressed.
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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By Sandesh Naik, Chief Financial Officer, AB Energia Solutions
There is a number that deserves more attention than it has received. 102 GW. That is India’s assessed floating solar potential, mapped by National Institute of Solar Energy (NISE) and released by the Ministry of New and Renewable Energy (MNRE) in the “Report on floating solar PV potential assessment of India” in June 2026. It takes India’s total assessed solar potential to 3,445 GWp – 3,343 GW from ground-mounted installations, and 102 GW sitting quietly on the surfaces of reservoirs, irrigation tanks and water bodies spread across the country. Unlocking even a fraction of this dormant resource will be pivotal to achieving India’s 500 GW non-fossil energy target and accelerating corporate decarbonization.
To put that in perspective, 102 GW is nearly equivalent to the total solar capacity India has installed over the past two decades. And today, we have deployed roughly 600 MW of it. That gap, between what is possible and what exists on the ground, is not a failure of ambition. It reflects where the sector is in its natural arc of development. For years, India’s renewable energy story has been told through a single geography: the sun-drenched deserts of Rajasthan, the flat expanses of Gujarat, the vast open terrain of the southern plateau. Floating solar asks us to look somewhere else entirely. It asks us to look down – at the water.
The land question needs to be addressed
India’s solar ambition is not in question. The target is 500 GW of non-fossil fuel capacity. The manufacturing infrastructure is being built. The policy machinery is functioning. But there is a structural consideration that is becoming an increasingly important part of the sector’s planning conversation: land.
Land acquisition has become one of the more time-consuming and complex aspects of utility-scale renewable energy development driving up soft costs and timeline risks. Large contiguous parcels near transmission infrastructure and demand centres are increasingly difficult to assemble, particularly in densely populated states where power demand is highest. The states that have historically led India’s solar story: Rajasthan, Gujarat, and Tamil Nadu, have built their capacity partly on geographic advantage that is not equally distributed across the country.
The NISE report changes the conversation
What NISE report does is convert floating solar from a conversation about potential into a conversation about specifics. In the NISE applied rigorous screening criteria: hydro-lake water bodies with a minimum area of 10 hectares, year-round water availability, depths between 3 and 30 metres, minimum global horizontal irradiation of 4.5 kWh per square metre per day, and proximity within 10 km of both road networks and electrical substations. Of the 10,725 square kms of mapped water body area across India, NISE identified 4,546 square kms as suitable, and applying a conservative 20 per cent utilisation cap yields the 102 GW figure.
The state-level picture is equally revealing. Maharashtra leads at 16.28 GW, followed by Madhya Pradesh at 14.89 GW, Karnataka at 13.69 GW, Odisha at 12.81 GW and Telangana at 10.72 GW. This ranking diverges from India’s established ground-mounted solar geography – Odisha and Telangana, for instance, rank well ahead of Gujarat, Rajasthan and Tamil Nadu, which have traditionally dominated India’s solar capacity addition.
This geographical reordering matters. States that have played a secondary role in the solar story find themselves holding significant floating solar potential. These states have the water, the irradiation and the demand. What they have needed is the policy framework and the project pipeline to match.
What floating solar will offfer
On the economic side, floating solar projects carry approximately 25 per ent higher upfront investment compared to conventional ground-mounted installations. The floating structures, anchoring systems, corrosion-resistant cabling and engineering requirements of working on water all contribute to capital cost. This is a real consideration that the sector needs to address honestly as it scales. But the cost picture is more complete when viewed alongside what floating solar delivers in return.
The cooling effect of water reduces panel temperatures, improving energy generation efficiency and increasing annual electricity output by an estimated 5 to 10 per cent compared to ground-mounted systems. Floating installations can also reduce water evaporation from reservoirs by 30 to 60 per cent by blocking direct sunlight – a benefit that carries its own economic and environmental value, particularly in water-stressed regions and for thermal/industrial power plants relying on captive reservoir water. They also help suppress the growth of algae in water bodies.
And there is the land consideration. When a project is developed on a reservoir, the complexities of land acquisition such as negotiation, legal processes, timeline risk are substantially reduced. That saving is not always visible in a line-item cost comparison, but it is very real in project development experience. Viewed holistically, the economics of floating solar are more competitive than an upfront cost comparison suggests, and they will continue to improve as the sector scales and domestic manufacturing ecosystems mature.
The policy window that is now open
The MNRE has signalled that a dedicated scheme to accelerate floating solar deployment is in development. This is a meaningful moment for the sector. A well-designed framework can address three areas that the current environment leaves underserved.
The first is regulatory coordination. Floating solar projects today require engagement with multiple authorities like irrigation departments, water resource agencies, state nodal bodies, environmental authorities and discoms; through separate processes that can significantly extend development timelines. A more integrated approval mechanism, drawing on models India has applied in other infrastructure sectors, could improve predictability considerably for developers and investors.
The second is financial support calibrated to where the sector is in its development curve. Viability gap funding, concessional financing and blended finance structures can improve project economics during the scale-up phase and enable the kind of tariff discovery that attracts broader private capital over time.
The third is state-level project pipeline creation. The potential is documented. Converting it into commissioned capacity requires investment in site identification, grid connectivity assessment and environmental baseline studies – foundational work that government agencies are well-placed to lead, and that reduces the risk and cost burden on individual developers while paving the way for smooth green financing and debt syndication.
The hybrid opportunity
One dimension of floating solar that merits more attention in Indian policy discussions is its compatibility with existing hydropower infrastructure. Hybrid floating solar and hydropower systems can generate solar electricity during daylight hours while conserving water for hydropower generation at night or during periods of low solar output. This complementarity is genuinely useful for grid management. Floating solar panels generate at peak when the sun is high; hydropower can be held in reserve and dispatched when solar generation tapers. Together, they can create a more despatchable clean energy system on a single site, making use of existing transmission connectivity. Furthermore, co-locating solar with hydro optimizes land use and significantly improves the project’s overall return on capital employed, accelerating payback periods for developers and institutional investors.
For states like Odisha, Karnataka and Maharashtra, which have both significant hydropower assets and the highest assessed floating solar potential, this represents a real near-term opportunity, not a distant technology proposition. It needs a policy home that enables developers to structure hybrid projects efficiently.
What the gap between 102 GW and 600 MW tells us
The distance between potential and deployment in floating solar is not primarily a technology gap. The technology is proven. Succesful projects demonstrate that floating solar performs: the efficiency gains from water cooling are real, the operational characteristics are well understood, and the reservoir utilisation model works in practice.
The gap is structural. It reflects the absence of a consolidated approval framework, the lack of standardised technical guidelines that give developers and lenders a shared reference point, and a financing environment that is still calibrating its understanding of floating solar’s risk profile relative to ground-mounted projects. It also represents a major environmental, social, and governance win; by utilising unutilised water bodies, floating solar preserves arable land for agriculture and significantly reduces the carbon offset footprint of industrial off takers. It also reflects the early stage of project pipeline development, the kind of visibility that draws capital at scale has not yet been created for this segment.
These are addressable gaps. They have been addressed before, in other segments, when the right combination of policy intent, institutional coordination and financial support was assembled. India did not reach 155 GW of installed solar capacity by accident. It reached that milestone through policy frameworks, manufacturing ecosystems and procurement pipelines that progressively reduced risk and attracted capital at scale.
Floating solar is ready for similar attention – not as a niche or a supplementary segment, but as a meaningful pillar of India’s next energy chapter. The NISE report has provided the foundation. The policy intent has been signalled. The technology is proven. The next step is translating that alignment into a project pipeline that developers and investors can build on.
Arevon Energy, Inc. has commenced construction of the 250 MW/1,000 MWh Cormorant energy storage project in Daly City, California. The project involves an investment of approximately $600 million. The company will own and operate the […]
At the National Centre for Photovoltaic Research and Education (NCPRE), IIT Bombay, the Ministry of New and Renewable Energy (MNRE) outlined India’s progress in developing silicon-perovskite tandem solar cells as part of its 100 GW […]
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TotalEnergies, together with Hydra Storage Holding and Reatile Renewables, has inaugurated the Hydra project in South Africa’s Northern Cape, describing it as Africa’s largest hybrid renewable energy project. The facility combines a 216 MW solar PV plant with a 500 MWh battery energy storage system (BESS). It was awarded under South Africa’s Risk Mitigation Independent Power Producer Procurement Programme (RMIPPPP). The project will supply 75 MW of dispatchable renewable electricity to the national grid between 5:00 a.m. and 9:30 p.m. under a 20-year power purchase agreement (PPA) with Eskom. It is expected to generate more than 400 GWh of electricity annually. The Hydra project is jointly owned by TotalEnergies (35%), Hydra Storage Holding (35%), and Reatile Renewables (30%).
Zambian President Hakainde Hichilema recently inaugurated the 100 MW Chisamba Phase II Solar Power Plant, doubling the capacity of the Chisamba Solar Complex to 200 MW. The $70 million project was completed in about 7 months and created more than 1,400 local jobs, according to the Ministry of Energy. The president said the project supports Zambia’s efforts to diversify its energy mix following the 2024 drought that impacted the country’s hydropower output. He reiterated the government’s target of adding 1 GW of solar capacity by the end of 2026 as part of its goal to expand total installed power generation to 10 GW by 2030.
The government also signed contracts with five contractor groups to develop 156 solar power plants, each with a capacity of 2 MW, under the Presidential Constituency Energy Initiative (PCEI). The ZMW 4.3 billion program will add a combined 312 MW of solar capacity to the national grid and is expected to create around 15,600 jobs. Approved in November 2025, the initiative aims to strengthen Zambia’s electricity supply through decentralized generation, with ZESCO overseeing project implementation and grid integration. The projects are scheduled for completion within 12 months.
The African Development Bank (AfDB) has approved up to $66 million for Phase I of the 500 MW Dandara Solar Project in Egypt, which includes a 100 MWh BESS. Located in Qena Governorate, the project is being developed by Norway’s Scatec. It will supply renewable electricity to the Aluminium Company of Egypt (EgyptAlum) under a 25-year PPA under a wheeling agreement with the Egyptian Electricity Transmission Company (EETC).
The financing package comprises $46 million from AfDB’s ordinary resources and $20 million from the Climate Investment Funds’ Clean Technology Fund (CTF). Additional funding is expected from other development finance institutions. Total project cost is estimated to exceed $290 million. Phase I of the project is scheduled to begin operations in early 2028 and is expected to generate about 1,373 GWh of electricity annually.
Chinese solar manufacturer Trinasolar has signed a memorandum of understanding (MoU) with Yemen-based Al-Raebi for Trading and Solar Energy Systems Company. Under the agreement, the duo will explore a potential 1.5 GW pipeline of large-scale solar projects in Yemen between 2026 and 2029. The companies will assess project opportunities, technical requirements, and cooperation models, with the potential deployment of Trinasolar’s TOPCon 3.0 PV modules. The agreement also covers opportunities across the wider Middle East and aims to support the expansion of reliable, affordable solar power in the region.
Hong Kong-listed Shanxi Installation Group has secured an EPC contract worth approximately RMB 1.5 billion for the 500 MW Al Kamil Phase I solar PV project in Oman. The company says this project marks its first major project in the Middle East. It also covers 2.5 years of operation and maintenance. Developed by EDF Group subsidiary EDF power solutions, the project is located in Al Kamil Wal Wafi, around 230 km from Muscat. Shanxi said the contract strengthens its presence in the Middle East and expands its international renewable energy portfolio.
South African coal miner Exxaro Resources, through its renewable energy business Cennergi, has commissioned the 68 MW AC Lephalale Solar Project (LSP), its first utility-scale self-generation renewable energy asset in South Africa. Located near the company’s Grootegeluk Mine in Limpopo, the behind-the-meter (BTM) solar PV plant comprises 129,024 modules installed across 185 hectares and is backed by a 25-year PPA with the mine. The ZAR 1.7 billion project is expected to generate around 176 GWh of renewable electricity annually to supply the mine. This will reduce its reliance on grid power during daylight hours. The facility has also been licensed for future BESS integration.
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Kumba Signs 63 MW Solar Power Offtake Agreement With Envusa Energy For Sishen Mine In South Africa SolarQuarter
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Explore how the group captive solar model compares with CAPEX and OPEX on cost, control, ownership, and long-term value for future-ready businesses in India
Jul 24, 2026
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For businesses, solar is no longer just a cleaner way to power operations. It is becoming a strategic call on ownership, capital, control, and long-term certainty. That is why the group captive solar model is drawing sharper attention, especially after the Electricity (Amendment) Rules, 2026 clarified captive power provisions and simplified rules for group captive arrangements.
The shift is important because every solar route changes the business equation differently. CAPEX gives ownership; OPEX offers lower upfront commitment, and group captive sits between the two with shared responsibility and scale. Understanding where each model stands can help businesses choose solar with greater confidence, not just greater intent.
For businesses planning a long-term shift to solar, choosing the best solar procurement model is less about a single tariff and more about striking the right balance among investment, control, risk, compliance, and scalability.
Group captive solar model balances ownership, scale and savings
For businesses, the group captive solar model brings the conversation back to what matters most: reliable renewable power, balanced responsibility, and long-term energy certainty. To understand the foundation behind any solar route, from panels and sizing to installation and maintenance, explore this guide to solar panels in India.
From surprising solar facts to smart energy tips, every spin uncovers a side of the sun you may not have seen before
The solar model a business chooses can quietly shape its energy economics for decades. CAPEX rewards those ready to own the asset, while OPEX makes adoption easier by removing the capital burden. For many commercial and industrial consumers, the group captive solar model offers a powerful middle path, combining shared ownership, long-term cost visibility, and large-scale renewable energy procurement. That is the real takeaway: solar adoption is easy to announce, but the smartest businesses will win by choosing the structure that protects cost, control, and certainty together.
Explore Tata Power’s solar solutions for savings, scale and cleaner energy
The frequently asked questions section is a reliable source for unlocking answers to some of the most crucial inquiries. Please refer to this section for any queries you may have.
The group captive solar model allows multiple electricity consumers to jointly participate in one solar project and use the power for captive consumption.
It usually includes –
Before signing a group captive solar PPA, businesses should review more than the quoted tariff. Important checks include –
A well-reviewed agreement helps ensure the group captive solar model remains financially attractive, compliant, and operationally practical over the contract period.
Yes, group captive solar can support corporate sustainability goals by helping businesses procure renewable electricity at scale. Since power is linked to a solar generation project, it can contribute to renewable energy procurement and decarbonization plans, subject to proper energy accounting and documentation. For companies with ESG or net-zero commitments, the model offers a practical route to cleaner power without depending only on rooftop capacity.
Approvals for group captive solar depend on the state, project location, and open access route.
They usually cover –
Before choosing the best solar procurement model, businesses should check approval timelines, consumer responsibilities, and state-specific regulations.
Group captive solar can reduce electricity costs for eligible businesses, but savings depend on more than the quoted tariff.
A strong group captive solar comparison should check –
The model works best when demand, location, and regulatory conditions align.
Yes, captive generators have the right to open access for carrying electricity to their own use, subject to the conditions and regulations set by the appropriate commission. For group captive solar projects, this means power can be supplied from an off-site solar plant to participating consumers through the grid. However, approvals, charges, metering rules, and timelines may differ across states, so state-level regulations remain critical.
The group captive solar model must meet two core captive conditions in India. Captive users must collectively hold at least 26% ownership in the generating plant and consume at least 51% of the electricity generated during the financial year. These requirements are important because the project must continue to qualify as captive. If the conditions are not met, the expected open access and surcharge-related benefits may be affected.
1. Captive Power Plant vs Group Captive Power in Open Access Green Energy: A Strategic Guide for Procurement and Operations Leaders
2. What is Group Captive Open Access? Why should businesses opt for Renewable Energy transition through this route?
3. What Are Captive Solar Projects?
4. Regulatory Landscape – Captive Consumption in India
5. Government issues draft revisions to captive power project rules
6. CAPEX vs OPEX solar model: Which one should you pick?
7. CAPTIVE / GROUP CAPTIVE
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July 24, 2026
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Adopting group captive solar? Don’t skip these 9 checks
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Schroders Greencoat has selected an asset manager for a UK solar portfolio, and Statkraft has taken FID on two sites.
July 24, 2026
Global renewable infrastructure manager Schroders Greencoat has selected Irish-based asset manager EnergyPro as technical asset manager for its portfolio of 27 solar PV projects across the UK.
The operational portfolio covers sites in Dorset, Somerset, Norfolk and Oxfordshire, the companies said, though did not specify which of Schroder’s assets the agreement covers.
EnergyPro is managing the assets as an expansion of an existing partnership with Schroders Greencoat, offering its services to Irish wind assets in Schroders’ portfolio already.
It is a significant expansion of EnergyPro’s asset management portfolio, which, before, only managed three assets in England.
Reporting by Jonathan Touriño Jacobo
Norwegian independent power producer (IPP) Statkraft took final investment decision in two solar PV plants with a combined 131MWp capacity in Q2 this year.
The two solar PV projects are the 58MWp Kilcush solar PV plant in Ireland and the 73MWp Stargoose project in Eastern England, a project for which the company secured planning permission back in 2022.
Elgin, Erova sign 15-year PPA for 112.6MW UK solar PV portfolio
In April, Statkraft issued notice that construction work was due to begin on the Kilcush project.
These two projects are part of more than 600MW of new renewable energy capacity that the IPP has made investment decisions on by the end of the first half of this year.
“Statkraft delivered strong results in the second quarter of 2026. Strategic divestments are now completed and planned cost reductions are on track. Over the past year, we have turned our ambitions into results. We have strengthened our core and reduced complexity and cost to improve competitiveness,” said Birgitte Ringstad Vartdal, president and CEO of Statkraft.
More on Statkraft’s activity so far this year is available to read in an article on our sister site, PV Tech.
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Molly Green
Section Editor, Informa
Molly joined the team in 2024 and has led coverage on the UK sites. Now shifting to a more global view, Molly is interested in how legislation shapes market dynamics, covering the intersection of policy design, investment patterns, and energy transition pathways.
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Greenvolt Power Sells 57.47 MWp Solar PV Project in Hungary to PPC Group for €64.2 Million SolarQuarter
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World’s First 10,800-Vehicle Car Carrier Equipped With 200-kW Solar Power System Delivered Marine Insight
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Wi Solar, a developer of commercial photovoltaic systems, and Karl Ditandy GmbH, a company specializing in natural stone, water engineering, and gabion construction, have partnered with mounting system manufacturer Diconal to develop a solution for installing solar modules on gabion structures.
Diconal presented the new system at this year’s Intersolar Europe trade show in Munich and sees potential applications, including solar installations on noise barriers. The first field test, however, was carried out on a smaller scale with a nine-module array installed at the former State Garden Show site in Bingen, Germany.
The main challenge was adapting a standard mounting system to the irregular geometry of stone-filled wire mesh gabions. Despite these constraints, the Bingen installation was completed successfully, according to Sven Endris, owner and managing director of Wi Solar.
“We are delighted that the practical field test was successfully completed. Our clamping design now allows photovoltaic modules to be mounted easily on gabions and installed in different sizes, making the clamps a scalable system solution,” Endris said.
According to the companies involved, Karl Ditandy was initially looking for a way to install PV modules on its gabion structures and approached Wi Solar for support. Based on the project requirements, Diconal – a sister company of Alutecta GmbH & Co. KG – developed a prototype that was subsequently tested and optimized in collaboration with the partners.
A key focus of the development process was ensuring dimensional accuracy between the substructure and the modules while keeping module spacing to a minimum. This required a mounting clamp that could be positioned flexibly, as gabion walls – especially taller structures – often have dimensional variations.
Unlike conventional mounting surfaces, gabion baskets cannot be aligned with millimeter-level precision. Their mesh grids may be slightly offset or vary in size, while protruding stones can block access to individual openings. The clamping system therefore needs to accommodate both vertical and horizontal deviations. This is achieved, among other features, through elongated holes aligned along both axes.
At the same time, the mounting solution must withstand potentially high wind-induced pressure and suction forces depending on the installation location. The design also needs to allow cable routing behind the modules and enable maintenance work with reasonable effort.
Wi Solar sees potential applications in any project where gabion walls are designed to accommodate PV modules, typically with a height of at least three meters. These include retaining walls, noise barriers, heavy-duty walls, slope stabilization structures, and privacy screens.
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ib vogt Begins Commercial Operations at 99 MWp Tantangan Solar Power Plant in the Philippines SolarQuarter
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Cypress Creek Renewables, the company proposing to build the Carriger Solar project near Goldendale, currently operates this solar farm in Vale, Ore. It is a 13-megawatt farm compared to Carriger, which would generate 160 megawatts of electricity.
Business Reporter
Cypress Creek Renewables, the company proposing to build the Carriger Solar project near Goldendale, currently operates this solar farm in Vale, Ore. It is a 13-megawatt farm compared to Carriger, which would generate 160 megawatts of electricity.
Yakama Nation and the developer of a 1,300-acre solar farm in Klickitat County have resolved a legal challenge to the project.
The settlement announced Wednesday includes actions to support preservation of treaty-reserved resources on public lands adjacent to the Carriger Solar Project, located about two miles northwest of Goldendale. The Yakama Nation filed the challenge against developer Cypress Creek Renewables.
“Cypress Creek has made significant commitments to meaningfully minimize and mitigate the project’s negative impacts to Yakama Nation by not only modifying the project itself, but also addressing cumulative impacts of the project,” said Star Diavolikis, public information officer for the Yakama Nation, in a news release.
The project is expected to generate 160 megawatts of alternating current solar energy and 63 MW of battery energy storage, enough power for 32,500 homes, according to documents from the developer and information on the Energy Facility Site Evaluation Council website. It will tie into the Bonneville Power Administration transmission system.
EFSEC officials recommended approval of the project last year, and Gov. Bob Ferguson approved the plans on Dec. 4, 2025 – with the expectation that company officials talk further with Yakama Nation leaders about protections for cultural resources in the area.
The governor’s approval required California-based Cypress Creek Renewables to provide a $100,000 grant to the Yakama Nation Cultural Resources Program once the project is operational. Also, tribal access to traditional and cultural properties must be maintained during construction.
Despite the grant, the tribe remained opposed to the project and filed a petition for judicial review on Dec. 31, challenging the EFSEC site certification process that culminated in Ferguson’s approval.
This week’s settlement should allow construction to begin on the project, which was planned to start this year to secure federal clean energy tax credits before they are ended by the Trump administration.
The joint statement issued by Yakama Nation and Cypress Creek officials said the settlement “is a result of respectful and solution-oriented communications that can happen during the permitting process and should be initiated by community-focused project developers.”
Both sides urged EFSEC and state Department of Natural Resources officials to help facilitate these types of solutions earlier in the permitting process.
Contact Joel Donofrio at jdonofrio@yakimaherald.com.
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Lithium prices drop as mining operations restart in China, Australia
July 24, 2026
Follow Mercom India on WhatsApp for exclusive updates on clean energy news and insights
The All India Solar Module Manufacturers urged Union Minister for New and Renewable Energy Pralhad Joshi to provide an 18-month, output-linked transition for the mandatory use of solar cells listed under the Approved List of Models and Manufacturers (ALMM) List-II across all project categories.
The lithium carbonate market remained highly volatile this year amid expectations of stronger global supply of the key battery material. Lithium carbonate futures in China fell to CN¥144.11 (~$21.28) per kg on July 21, a decline of nearly 28% from more than CN¥200 (~$29.53) per kg in May, according to Trading Economics.
On the sidelines of the Mercom India Renewables Summit 2026, Bhavesh Kumar Rathod, Founder and Managing Director at Soleos Energy, spoke about domestic manufacturing, battery energy storage, open access, transmission bottlenecks, financing, and the company’s plans to support industrial decarbonization.
Stricter regulations and project oversight can discourage speculative developers, but they may also inadvertently affect genuine developers facing legitimate execution challenges that delay project timelines. According to Shri Venkatesh, Founding Partner at SKV Law Offices, India’s electricity regulations must strike a balance between stronger oversight and adequate flexibility for private developers.
In an interview on the sidelines of the Mercom India Renewables Summit 2026, held in New Delhi on July 1 and 2, Kalthia talks about India’s solar manufacturing ecosystem, export opportunities, timelines for the ALMM, battery energy storage, and Kosol’s plans to foray into battery cell manufacturing.
The Maharashtra Electricity Regulatory Commission directed Maharashtra State Electricity Distribution Company (MSEDCL) to pay ₹1.14 billion (~$11.84 million) for delayed payments to wind energy developers. It directed MSEDCL to pay Vena Energy ₹710.96 million (~$7.37 million) as late payment surcharge and ₹431.52 million (~$4.47 million) as interest for delays relating to invoices issued between July 2020 and November 2024.
Electric two-wheeler manufacturer Ather Energy raised approximately ₹13 billion (~$134.74 million) through a qualified institutional placement of equity shares.
PFC Consulting invited bids to establish an intrastate transmission system for the 400/220 kV Malegaon (Saundane) air-insulated substation in the Nashik district of Maharashtra.
Waaree Renewable Technologies, the engineering, procurement, and construction arm of the Waaree Group, reported consolidated revenue from operations of ₹9.24 billion (~$95.7 million) for the first quarter of the financial year (FY) 2027, a 53.23% year-over-year (YoY) increase from ₹6.03 billion (~$62.49 million).
Adani Green Energy posted revenue of ₹42.80 billion (~$443.52 million) in Q1of FY 2027, an increase of 29% YoY from ₹33.12 billion (~$343.21 million). The company attributed the growth primarily to higher electricity sales and the expansion of its operational portfolio.
Surat-based solar module manufacturer Navitas Solar entered into a five-year partnership with California-based perovskite technology company Caelux Corporation to develop and manufacture 5 GW of hybrid tandem solar modules in India.
Malaysia’s Ministry of Energy Transition and Water Transformation launched the sixth Large-Scale Solar program, offering 2,650 MW of solar capacity and 1,250 MW of battery storage capacity across three procurement packages.
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Energy investment firm Panamint Capital has broken ground on the 1.2GWdc Big Rooter Power solar PV project at its Twin Oaks power station in Robertson County, Texas.
The US$1.7 billion project, located between Dallas and Houston, will be constructed on an existing coal mining site. According to the company, it will be “the largest solar project built at an existing coal mining site in North America”.
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Construction has started on the first phase, Big Rooter West, a 491MWdc project scheduled to enter commercial operation in August 2028. The second phase, Big Rooter East, will add 658MWdc, with construction expected to begin in December 2026 ahead of commercial operation in August 2029.
“Big Rooter Power represents our vision for getting more out of America’s energy infrastructure and ensuring America’s energy dominance,” said Apolka Totth, Panamint’s CEO.
“When Big Rooter is complete, the Twin Oaks complex will have 1.5GW of operating thermal and renewable power, in addition to over 20 miles of new 345kV transmission, 1.6GWh of battery energy storage and 790MW of Batch Zero data center capacity under development across our 10,000-acre site.”
Panamint said the two phases will create more than 800 construction jobs.
For the engineering, procurement and construction (EPC) scope, Panamint has selected SOLV Energy, which will deliver the solar array alongside substation and transmission infrastructure. In 2025, SOLV announced plans to build 6GW of solar-plus-storage capacity across the US, including projects for Panamint.
First Solar will supply approximately two million solar modules for the project, manufactured at its facilities in Ohio, Louisiana and Alabama. The project will also deploy Nextpower’s NX Horizon solar tracker systems, incorporating Hail Pro-75 and NX Navigator software.
Panamint Capital, a Nevada-based energy infrastructure developer majority owned by Global Atlantic Financial Group, manages more than 3GW of operating and development-stage conventional and renewable energy assets across North America.
Brisbane-headquartered clean energy developer Ark Energy has the green light to begin the construction phase of it’s Richmond Valley 435 MW solar farm and 275 MW / 2,200 MWh battery energy storage system (BESS).
The proposed solar farm is reported to deploy approximately 730,000 bifacial solar panels rated at 690 W each.
Located 25 kilometres south of Casino in the northern rivers region of New South Wales (NSW), the $1.3 billion (USD 900 million) solar and long-duration Lithium-iron phosphate (LFP) BESS project secured financial investment decision (FID) via an extraordinary board meeting for parent company Korea Zinc in Seoul.
Ark Energy is reported to expect a financing package of $586 million in equity funding and $716 million in debt financing.
The company says the project is the first build-to-own in Ark Energy’s development portfolio to secure FID.
The financing will fund the hybrid project’s priority stage, consisting of a 200 MW solar farm to be scaled up to 435 MW with full approval, and an 8-hour BESS.
It is also one of the first hybrid projects in the National Electricity Market (NEM) designed with a single point of connection to Transgrid’s 330 kV network, reducing sub-station footprint and grid integration complexity.
Ark Energy Chief Executive Officer Michael Choi said the approval represents Korea Zinc’s endorsement and confirms its continued commitment to supporting the project.
“We are thrilled to have reached this major milestone and look forward to moving the project into the next phase of financial close and construction,” Choi said.
The project has a Long-Term Energy Service Agreement (LTESA) under the NSW Electricity Infrastructure Roadmap’s incentive scheme and is listed in the Australian government’s National Renewable Energy Priority List.
In 2025, Ark Energy signed a supply agreement for the BESS with South Korean energy and solar solutions company Hanwha Energy and an early contractor involvement (ECI) agreement with Spain-headquartered infrastructure developer Elecnor Australia.
Financial close is targeted for September 2026, followed in October 2026 by the start of construction aiming for the project to be fully operational by January 2029.
Richmond Valley solar and BESS is to be built on land historically used for private commercial forestry.
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TNN | Posted July 24, 2026 02:34 PM
Innovators from National Institute of Technology (NIT) Rourkela have developed an Artificial Intelligence (AI)-powered autonomous system for monitoring and cleaning solar plants. The innovation addresses the challenge of maintaining clean solar plants to ensure peak power generation without regular human intervention.
The system has been developed by Prof Arun Kumar, assistant professor, in collaboration with Prof Bibhudatta Sahoo, professor, and research graduates Lopamudra Hota and Biraja Prasad Nayak, from the Department of Computer Science and Engineering, NIT Rourkela. The team has secured an Indian patent titled, ‘Federated Learning based Autonomous System and Method for Monitoring and Cleaning Solar Plant’.
As solar energy capacity in India is expanding rapidly, large-scale solar farms, particularly in arid and dusty regions, face energy losses of up to 40% caused by dust, bird droppings, industrial pollutants, and other debris accumulated on solar panels. Conventional methods/practices used to clean solar panels are labour-intensive and require a large amount of water. Such practices usually rely on scheduled maintenance of the panels rather than on panel conditions.
To address these limitations, the NIT Rourkela research team has developed an autonomous mechanism powered by Federated Learning (FL), the invention provides an AI-driven framework leverages FL to enable intelligent, privacy-preserving monitoring, fault detection, and optimised cleaning recommendations for solar panels. The technology has been validated through simulation and is currently at Technology Readiness Level (TRL)-3, demonstrating proof-of-concept under controlled experimental conditions.
A key feature of the developed innovation is its privacy-preserving federated learning architecture. Contrary to conventional AI-operated systems, which share raw operational data with a centralised server, the developed technology shares encrypted data, thus addressing concerns related to privacy, bandwidth, cybersecurity, and scalability.
Prof Kumar said, “The patented system combines federated learning, edge computing, artificial intelligence, autonomous cleaning, and predictive maintenance into a single integrated sand-box platform. Notable features, including real-time edge intelligence, autonomous fault detection, selective need-based cleaning, reduced water consumption, and lower maintenance costs, make it a one-of-its-kind system.”
The developed technology can be applied directly to utility-scale solar power plants, floating solar farms, rooftop photovoltaic installations, industrial solar parks, smart city energy infrastructure, defence installations, and remote off-grid renewable energy systems.
Prof Sahoo said, “While current market solutions suffer from high capital costs and limited intelligence, our developed system integrates advanced AI capabilities for autonomous operation. Once scaled for field implementation, the technology is expected to deliver superior performance and features at approximately 10% of the cost of existing systems.”
As next step, the research team plans to test the invention for the development of a hardware prototype integrated with an IoT sensing infrastructure, and advance from simulation-based proof-of-concept to prototype validation through pilot deployments.
Also, they target to collaborate with government agencies and industry partners to undertake field deployments and technology transfer of the developed technology. The team also plans to integrate drone-assisted inspection, multi-agent collaborative cleaning, and predictive energy yield forecasting in the next stage of this innovation.
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Keene residents weighed in on three concepts for a solar-powered pavilion planned for Gilbo Avenue that would generate clean energy while creating covered event space downtown.
KEENE, N.H. (MyKeeneNow) A proposed solar-powered pavilion on Gilbo Avenue is moving closer to reality, with city officials gathering public feedback this week on how the structure should look and function before final designs are completed.
The project, planned for the municipal parking lot next to the Farmers’ Market of Keene, is intended to do more than generate renewable energy. City leaders envision the pavilion as a year-round community gathering space that can support the farmers’ market, festivals, food trucks and other downtown events while producing enough electricity to offset the city’s downtown electrical use for streetlights, traffic signals, holiday lighting and public event power.
During a public information session Wednesday at the Keene Public Library’s Cohen Hall, project consultants outlined the vision and presented three conceptual designs for residents to evaluate. Similar concepts were also discussed later that evening with the City Council’s Municipal Services, Facilities and Infrastructure Committee.
The approximately 230-foot-long timber structure would be topped by a 75-kilowatt solar array capable of generating about 36,000 kilowatt-hours of electricity annually. The pavilion is expected to include LED lighting, electrical hookups for vendors and food trucks, and an integrated drainage system designed to prevent water and ice from dripping between the solar panels.
Officials said the pavilion grew out of two goals identified during planning for downtown improvements: expanding the city’s sustainability efforts while preserving as much of the existing downtown tree canopy as possible.
Rather than placing solar panels throughout the downtown, the city chose to concentrate renewable energy production at the Gilbo Avenue site, where it can also provide sheltered public space.
The project received funding through the Northern Border Regional Commission’s Timber for Transit Program, which promotes innovative uses of advanced wood products while supporting the forest-products economy in New Hampshire and neighboring states. Because of the grant, the pavilion will prominently feature engineered timber construction.
The estimated overall project budget is about $2.2 million, with roughly 80 percent funded through the federal grant. The city’s share is expected to be about $440,000.
Consultants from NXTGEN Clean Energy Solutions presented three concepts that all produce roughly the same amount of solar power but differ in appearance, cost and functionality.
The least expensive option features a single sloping roof angled to the south for maximum solar production. Estimated to cost about $1.62 million to build, it offers the simplest design and provides the greatest ease for snow removal, vehicle circulation and long-term maintenance.
A second concept expands on that design by extending part of the roof over the adjacent sidewalk, creating additional shelter for pedestrians walking between parked vehicles and downtown businesses. That version carries an estimated construction cost of about $1.69 million.
The third alternative uses a traditional gable roof intended to resemble a New England train platform or covered bridge. While some participants said it best complements the character of downtown Keene, consultants noted it would require additional structural supports within the parking area, creating more obstacles for vehicles and snowplows while increasing construction costs to about $1.74 million.
Discussion at Wednesday’s library session extended beyond roof styles.
Residents asked whether additional solar panels could be installed in the future to generate more electricity than the initial 75-kilowatt system, whether the pavilion could be repositioned to better protect mature trees, and if relocating it could improve safety for Farmers’ Market vendors by moving activity farther away from Gilbo Avenue traffic.
Participants also suggested modifying some of the roof designs by extending the simplest sloped roof farther over the sidewalk instead of using a more complicated roofline that could collect leaves and debris.
Parking drew considerable attention as well. Some questioned whether covered parking spaces should command higher parking fees, expressing concern that premium pricing could create the perception that better parking would only be available to those willing to pay more.
Others discussed opportunities to incorporate covered bicycle parking or relocate aging electric vehicle charging stations as part of the broader project.
Officials emphasized the pavilion is intended to serve multiple purposes rather than simply cover parking spaces.
The structure would provide electrical service for food trucks and market vendors, eliminating the need for portable generators during events. Lockable electrical panels would help prevent vandalism while allowing power to be available when needed for festivals, concerts and community gatherings.
The pavilion’s drainage system is also designed to address a common problem with solar canopies by channeling rainwater and melting snow away from pedestrians instead of allowing water or icicles to form between solar panels.
City staff and consultants will review comments gathered from Wednesday’s public sessions, as well as feedback from farmers’ market vendors, downtown businesses and event organizers, before refining a preferred design.
The selected concept will then move into detailed engineering, including final structural design, drainage, electrical systems and site layout, before being advertised for competitive construction bids.
Public Works Director Don Lussier has previously said construction is anticipated to begin next summer.
Nicole Colson is the editor-in-chief of MyKeeneNow. She can be reached at 603-352-9230, X-322.
Cheshire Medical Center has surpassed its $42.6 million fundraising goal as work continues on a second linear accelerator and other major projects.
Keene residents weighed in on three concepts for a solar-powered pavilion planned for Gilbo Avenue that would generate clean energy while creating covered event space downtown.
SWANZEY, N.H. (MyKeeneNow) After helping guide Monadnock Ford through several years of growth […]
Keene’s MSFI Committee advanced a proposed four-way stop, reviewed Robin Hood Park renovations and received updates on several major city projects.
Drivers should expect lane reductions, a slip lane closure and continued parking restrictions in downtown Keene as Central Square construction continues through Friday.
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Winning with AI
Facing rapid growth, the company built AI capabilities to balance scale, efficiency, and risk.
Rapid growth and rising operational complexity pushed TCL Photovoltaic Technology (TCL PV Tech), a new energy company within TCL Corporation, to embrace artificial intelligence. Between 2022 and 2025, the company’s revenue surged from roughly RMB 600 million to RMB 20 billion. At the same time, highly dispersed projects, more intricate processes, and shifting policy environments heightened the demand for efficiency, consistency, and risk management.
AI as a foundational capability—not just a tech initiative—answered TCL PV Tech’s question: How can we reduce costs, improve efficiency, and ensure high-quality scale growth? With Bain’s guidance, the company zeroed in on a set of high-impact AI use cases at the intersection of transformation potential and capability maturity.
auditing process cost reduction
Rather than focus on standalone pilots, TCL PV Tech prioritized solving pain points—those critical yet constrained processes that would hinder sustainable growth. In collaboration with Bain, the organization introduced:
• Intelligent inspection, which reduced reliance on human judgment for processes like site survey and final grid connection
• Real-time analysis and forecasting of power markets to boost efficiency and accuracy
• AI-powered recognition to continuously monitor power stations and flag potential faults early, improving the speed and accuracy of maintenance responses
TCL PV Tech’s dedicated AI service group continues to scale AI across the business, embedding it in core capabilities to balance efficiency gains with risk control as the company grows. But beyond the tactical wins, Bain helped the company adopt an end-to-end transformation mindset. Faced with a highly uncertain business climate, the company built a sustained capability through process and organizational change. In that context, the organization’s AI-enabled transformation was not a one-time rollout but a continuous journey of iteration and refinement.
First, major, immediate pain points need to be addressed. Second, tangible results must be [achieved]. Visible success helps more colleagues recognize the real benefits AI brings and motivates them to go further.
Ms. Ricky He, General Manager, TCL Photovoltaic Technology
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Financial close is anticipated in September 2026, with construction scheduled to begin the following month.
Australian renewable energy company Ark Energy has received approval for a financial investment decision (FID) on its planned A$1.3bn ($908.4m) Richmond Valley solar farm and battery energy storage system (BESS) in New South Wales (NSW).
Ark Energy’s parent company, Korea Zinc, approved the resolution at an Extraordinary Board Meeting in Seoul on 21 July 2026.
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The funding package comprises A$586m in equity and A$716m in debt financing.
The Richmond Valley Solar Farm and BESS mark the first instance in Ark Energy’s development pipeline where a build-to-own project has obtained an FID.
Financial close is anticipated in September 2026, with construction scheduled to begin the following month.
The start of operations is planned for January 2029.
Ark Energy secured planning, environmental approvals, grid connection and government support under a long-term energy service agreement during a four-year development process.
The current financing targets the project’s priority stage, which includes a 200MW-alternating current solar farm and a lithium-iron phosphate BESS with a power capacity of around 275MW and a storage capacity of 2.2GW-hours.
Ark Energy CEO Michael Choi said: “This approval represents a strong endorsement from Korea Zinc and confirms its continued commitment to supporting the Richmond Valley project and Ark Energy’s growth ambitions.
“We are thrilled to have reached this major milestone and look forward to moving the project into the next phase of financial close and construction.”
Planning approval was granted by the NSW Government in October 2025, followed by unconditional federal approval under the Environment Protection and Biodiversity Conservation Act 1999 from the Department of Climate Change, Energy, the Environment and Water in December 2025.
Grid connection was secured in June 2026.
In March 2025, Ark Energy reached a supply agreement with Hanwha Energy for the battery system and entered an Early Contractor Involvement agreement with Elecnor Australia in September 2025.
The company stated that the development is expected to support more than 850 jobs at peak construction and generate approximately A$180m in local expenditure.
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China and India should bear the well-being of humanity in mind, demonstrate a sense of responsibility as major …
China added 72.07 GW of new solar capacity in the first half of 2026, down 66.04% year on year, according to data released by the National Energy Administration (NEA) on July 22. China installed 12.48 GW of new solar capacity in June, down 13.09% from 14.36 GW in the same month last year. By the end of June, the country’s total installed power generation capacity had reached 4.04 TW, up 10.8% year on year. Solar capacity totaled 1.27 TW, up 15.8%, while wind power capacity reached 680 GW, an 18.5% increase.
Shenzhen Energy said on July 22 that its subsidiary Sunon Asogli Power (Ghana) Ltd. plans to invest $34 million in a 50 MW solar project in Ghana’s Savannah Region. The project will be located in the Central Gonja District and will use 540 W bifacial monocrystalline PV modules and 300 kW string inverters. It will also include grid-connection infrastructure, including main transformers, 161 kV outdoor distribution equipment, 34.5 kV switchgear, and SVG systems. The plant is expected to connect to the existing 161 kV transmission network through a T-connection. Shenzhen Energy said the project marks its first overseas solar investment.
Dinto Solar said on July 21 that it had secured the 1 GW HJT module supply lot in China Datang Group’s 2026-27 PV module framework procurement tender. The tender has a total estimated capacity of 11 GW and includes three categories: 6 GW of N-type TOPCon modules, 1 GW of N-type HJT modules, and 4 GW of N-type BC modules.
The Silicon Industry Branch of the China Nonferrous Metals Industry Association (CNMIA) said on July 22 that domestic polysilicon trading remained subdued this week. N-type recharging polysilicon prices ranged from CNY 30,500 ($4,485) to CNY 33,000/ton ($4,853/ton), with an average price of CNY 32,000/ton, down 1.54% week on week. N-type granular silicon prices ranged from CNY 30,500 ($4,485) to CNY 32,000/ton ($4,706/ton), averaging CNY 31,000/ton, down 2.21%. The association said weak end-market demand, rising inventories, and policy changes affecting the cell segment have increased pressure on polysilicon producers. Downstream buyers remain cautious amid continued market uncertainty. The association reported additional wafer price declines on July 23. Average prices for N-type G10L wafers (182 × 183.75 mm, 130 μm) fell 2.35% week on week to CNY 0.83 ($0.12) per piece. N-type G12R wafers (182 × 210 mm, 130 μm) averaged CNY 0.93 ($0.14) per piece, down 2.11%, while N-type G12 wafers (210 × 210 mm, 130 μm) declined 1.75% to CNY 1.12 ($0.16) per piece. The association said industry operating rates were largely unchanged from the previous week. Two leading manufacturers were operating at 54% and 56%, integrated producers at 58%-60%, and other manufacturers at 56%-78%.
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The cell was run consistently under light for 770 hours (about 32 days).
Photo Credit: iStock
Researchers have pushed a promising form of solar technology to a new milestone.
The team built a solar cell with 27.3% efficiency, which is one of the highest values reported for this technology.
The more efficient solar cells are, the more electricity they can generate from the same rooftop, solar farm, or building surface, helping lower energy costs while cutting pollution.
According to pv magazine, teams at Helmholtz-Zentrum Berlin (HZB), Universität Potsdam, and Swiss Federal Laboratories for Materials Science and Technology (Empa) created the solar cells using a bilayer made up of two materials: graphene oxide (GO) and a self-assembled monolayer (SAM).
Together, the layers outperform each material when they’re used alone. The efficiency then increased from 23.6% to 25.1%.
The researchers then adjusted the “bandgap” — the recipe of the middle perovskite layer — so that it absorbed more sunlight, pushing the efficiency up to 27.3%.
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The cell was run consistently under light for 770 hours (about 32 days) and still produced 90% of the power it started with — meaning there was barely any drop-off. Cells built the old way (before the GO/SAM bilayer) degraded faster and lost more power during the same test.
Solar cells that convert more sunlight into electricity can make clean energy cheaper and more practical for everyday use. If future solar panels can generate more power from the same footprint, homeowners could get more from limited roof space, while businesses and cities could produce more electricity without expanding installations.
This new solar technology has drawn major interest because it could be cheaper and easier to manufacture than conventional silicon-based designs. If researchers can continue improving both efficiency and stability, the technology could help speed the rollout of lower-cost solar products.
More affordable solar power can reduce reliance on dirty energy sources that contribute to harmful air pollution and planet-warming emissions. Cleaner electricity can support healthier communities while helping families and companies manage rising utility costs.
Much of the effort centers on interface engineering, which is the practice of designing and modifying the layers between different materials stacked inside a solar cell, rather than focusing on the main light-absorbing material itself, according to a 2024 study.
Further improvement may still be possible. The researchers said that lowering charge-transport resistance, improving perovskite quality, and better aligning energy levels could increase fill factor and voltage and potentially move efficiency beyond 30%.
“Overall, our findings demonstrate the immense potential of SAM-based all-perovskite multi-junctions and bring this promising technology a step closer to higher industrial readiness levels,” the researchers told pv magazine.
The technology remains in development rather than ready for immediate purchase. Still, breakthroughs like this can help shape the next generation of solar products, which could eventually offer lighter, more versatile, and more efficient panels for homes, apartments, vehicles, and commercial buildings.
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Energiekontor AG, a Germany-based developer and operator of wind and solar parks, has signed a 10-year power purchase agreement with EHA Energie-Handels-Gesellschaft. The agreement covers the planned Kolitzheim-Herlheim solar park, which will supply electricity to drugstore retailer dm in Bavaria, Germany. The project will have an installed capacity of around 11 MW and is scheduled for commissioning in the first half of 2027. Once operational, it is expected to generate more than 13 GWh of electricity annually to supply renewable power to dm stores. The project will be developed without support under Germany’s Renewable Energy Sources Act (EEG). EHA will manage the physical PPA, balancing services and electricity integration into dm’s portfolio. The solar park will also include sheep grazing alongside photovoltaic generation.
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India has risen from a negligible solar player to the world’s third-largest solar market, driven by rapid clean energy growth
Twenty-five years ago, solar power was a curiosity in India, not a source of energy or strategy. Today it is the single fastest-growing pillar of the country’s power system, and India has climbed from a rounding error in global rankings to the world’s third-largest solar market, trailing only China and the United States on cumulative installed capacity and in 2025, overtaking the US outright in the volume of new capacity added in a single year.
This is not an incremental improvement. It is a structural repositioning of India within the global energy order, and the data laid out year by year tells the story better than any other.
Global solar photovoltaic capacity crossed a historic threshold in 2025, reaching approximately 2,383 GW worldwide, with roughly 510 GW added in the year alone, where more capacity was installed in twelve months than existed on the entire planet as recently as 2018. China remains the dominant force, alone accounting for around 1,200 GW of cumulative capacity, more than the next nine countries combined and adding close to 382 GW in 2025. But the data below the summit is where India’s rise becomes visible:
India has already overtaken Japan and Germany, two economies that led global solar deployment through the 2000s and early 2010s, to claim third place in the world. More strikingly, when it comes to new capacity added during 2025 rather than cumulative stock, India pulled ahead of the United States for the first time, becoming the world’s second-largest solar market by annual installation, with China’s 2025 additions running at roughly eight times India’s.
To appreciate the scale of this shift, the year-by-year trajectory needs to be seen in full:
At the turn of the millennium and for most of the 2000s, India’s solar capacity was effectively negligible, with a few isolated pilot and off-grid installations; after 2020, its near appearing in any global ranking table. The real inflexion point came with the launch of the National Solar Mission in January 2010, which set the country on a mission-mode path rather than leaving solar to incidental growth.
The pace through the first mission phase was modest by later standards. It was the revision of the national target in 2015, scaling ambition from 20 GW to 100 GW of solar capacity by 2022, backed by a planned investment of $100 billion that changed the trajectory altogether. What followed was not linear growth but compounding acceleration: capacity that took nearly four years to cross 3 GW after 2014 needed barely two years to add the next 20 GW and by FY 2025-26, a single year alone contributed a record 44.61 GW of new solar capacity more than double the previous year’s addition and itself larger than the country’s entire cumulative capacity as recently as 2020.
If we put it another way, the solar capacity has grown roughly 53 times over since March 2014 alone, from 2.82 GW to over 150 GW in barely a decade, a rate of expansion with few parallels among large economies.
Three structural shifts explain why India’s rise is a genuine competitive gain rather than simple scale-catching-up:
First: India overtook the US in annual new capacity for the first time in 2025. This matters more than cumulative rank, because it signals the trajectory going forward. The United States added roughly 38 GW of solar in 2024; India’s FY 2025-26 addition of 44.61 GW comfortably exceeds that pace, even before accounting for further US slowdowns linked to shifting federal incentive structures.
Second: the composition of India’s growth has diversified. Of the 150.26 GW installed as of March 2026, roughly 110.43 GW is utility-scale, 25.73 GW is rooftop solar, and 14.10 GW comes from PM-KUSUM and off-grid agricultural applications. This is not a story of a handful of giant desert solar parks alone as China’s growth largely is, but of a base broadening simultaneously across utility plants, commercial and residential rooftops and farm-level solar pumps, thus making the growth more resilient to disruption in any single segment.
Third: India is building the manufacturing base to match the installation base, a distinction few rapidly-growing solar markets achieve simultaneously. Roughly 98 GW of solar module manufacturing capacity was added in FY 2025-26 alone, taking India’s cumulative module production capacity to around 172 GW, with some industry estimates placing it closer to 210 GW. As a direct consequence, India’s solar module imports fell roughly threefold between FY 2024-25 and FY 2025-26. This is the Aatmanirbharta dimension of the solar story where India is not merely importing panels to hit installation targets, as many fast-growing markets do, but is simultaneously localising the supply chain that feeds them.
None of this scale materialised by luck. A sequence of policy interventions underlies each phase of acceleration: The Jawaharlal Nehru National Solar Mission (2010) provided the initial institutional push. The 2015 target revision to 100 GW by 2022 forced a step-change in ambition. Fifty solar parks of 500 MW-plus capacity each were rolled out to provide developers with pre-cleared land and evacuation infrastructure, removing one of the biggest execution bottlenecks that slows renewable projects elsewhere. The PM-KUSUM scheme extended solar directly to the agricultural sector, decentralising benefits to farmers rather than concentrating them in utility-scale plants alone.
And most recently, the PM Surya Ghar: Muft Bijli Yojana, targeting one crore rooftop solar installations, has pushed adoption into the residential segment at a scale few other countries have attempted. On the manufacturing side, production-linked incentive schemes for solar module and cell manufacturing directly targeted the import-dependency that had long been India’s Achilles heel a dependency now visibly shrinking, as the collapse in module imports demonstrates.
None of this should be thought of as India having closed the gap with China, which remains in a category of its own: its cumulative capacity is still roughly eight to ten times India’s and its single-year addition in 2025 exceeded India’s entire installed base. China’s dominance in solar manufacturing, particularly in polysilicon and wafer production, also remains structurally unmatched and global supply chains will continue to run through Chinese capacity for years regardless of India’s own manufacturing build-out.
But the comparison that matters strategically is not with China’s scale, which reflects a different economic model and decades of earlier industrial planning, but with India’s own historical trajectory and its immediate competitors the US, Japan and Germany. On that comparison, the shift is unambiguous: a country that had no meaningful presence in global solar rankings twenty-five years ago has overtaken two G7 economies in cumulative capacity and pulled ahead of the world’s largest economy in annual new installations, within a single decade of sustained policy focus.
The global solar race of 2025 is not simply a story of China extending its lead. Beneath that headline lies a genuine reordering of the rest of the field, and India sits at the centre of that reordering. From 161 MW in 2010 to over 150 GW by early 2026, from complete absence in the top ten to third place globally; from near-total import dependence to a rapidly localising manufacturing base, the trajectory is one of a country that identified a strategic opportunity and executed on it with a consistency rare in large, diverse economies.
The distance to China remains vast, and the road to India’s own 2030 non-fossil targets is not yet complete. But on the question posed at the outset, is India winning the global solar race? The twenty-five-year data record leaves little room for ambiguity.
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T1 Energy, First Solar, Enphase Energy, Solaris Energy Infrastructure, Nextpower, SolarEdge Technologies, and Sunrun are the seven Solar stocks to watch today, according to MarketBeat’s stock screener tool. Solar stocks are shares of publicly traded companies whose business is tied to the solar energy industry, such as firms that manufacture solar panels, develop solar power systems, or produce related equipment and services. For stock market investors, these stocks are often viewed as a way to gain exposure to the growth of renewable energy, but their prices can be sensitive to changes in government policy, technology trends, commodity costs, and overall demand for solar power. These companies had the highest dollar trading volume of any Solar stocks within the last several days.
T1 Energy Inc. is an energy solutions provider building an integrated supply chain for solar and batteries. T1 Energy Inc. , formerly known as FREYR Battery, is based in NEW YORK.
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First Solar, Inc., a solar technology company, provides photovoltaic (PV) solar energy solutions in the United States, France, Japan, Chile, and internationally. The company manufactures and sells PV solar modules with a thin film semiconductor technology that provides a lower-carbon alternative to conventional crystalline silicon PV solar modules.
Read Our Latest Research Report on FSLR
Enphase Energy, Inc., together with its subsidiaries, designs, develops, manufactures, and sells home energy solutions for the solar photovoltaic industry in the United States and internationally. The company offers semiconductor-based microinverter, which converts energy at the individual solar module level and combines with its proprietary networking and software technologies to provide energy monitoring and control.
Read Our Latest Research Report on ENPH
Solaris Energy Infrastructure, Inc. is a holding company, which engages in the manufacture of patented mobile proppant management systems that unload, store, and deliver proppant to oil and natural gas well sites. Its products include Mobile Proppant and Mobile Chemical Management Systems, and Inventory Management Software.
Read Our Latest Research Report on SEI
Nextpower, formerly known as Nextracker, an energy solutions company, provides solar trackers and software solutions for utility-scale and distributed generation solar projects in the United States and internationally. The company offers tracking solutions, which includes NX Horizon, a solar tracking solution; and NX Horizon-XTR, a terrain-following tracker designed to expand the addressable market for trackers on sites with sloped, uneven, and challenging terrain.
Read Our Latest Research Report on NXT
SolarEdge Technologies, Inc., together with its subsidiaries, designs, develops, manufactures, and sells direct current (DC) optimized inverter systems for solar photovoltaic (PV) installations in the United States, Germany, the Netherlands, Italy, rest of Europe, and internationally. It operates in two segments, Solar and Energy Storage.
Read Our Latest Research Report on SEDG
Sunrun Inc. designs, develops, installs, sells, owns, and maintains residential solar energy systems in the United States. It also sells solar energy systems and products, such as panels and racking; and solar leads generated to customers. In addition, the company offers battery storage along with solar energy systems; and sells services to commercial developers through multi-family and new homes.
Read Our Latest Research Report on RUN
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