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Choose edition Search singapore asia world opinion life business sport Visual Podcasts SPH Rewards STClassifieds Paid press releases Advertise with us FAQs Contact us Sign up now: Get ST's newsletters delivered to your inbox Published Feb 21, 2026, 03:36 AM Updated Feb 21, 2026, 03:36 AM HAVANA, Feb 20 – Cubans are scrambling to install solar panels on their homes, shops and vehicles to combat extended blackouts as Washington prevents oil shipments from reaching the Caribbean's largest island, contributing to electricity generation shortfalls. U.S. sanctions and a deep economic crisis have for years made it impossible for the government to buy enough fuel, and a more recent drought in shipments from Venezuela and Mexico due to U.S. tariff threats has worsened existing shortages. CHINA HELPS TO FINANCE SOLAR GROWTH Cuba's government, helped by Chinese financing and equipment donations, has installed upwards of 1,000 megawatts of solar generation in the past year, and promises to double that capacity in the coming years. But some private citizens have taken matters into their own hands. "Given the frequent outages, which pretty much stop you from doing anything, a friend offered to help me invest in panels and set everything up," Havana resident Roberto Sarriga told Reuters. Sarriga said that with the help of solar panels he could have internet, charge his phone so people can locate him and power a TV to keep his elderly mother entertained watching her favorite soap operas. "The idea was to at least have the basics covered." The panels, imported and sold in dollars, are well out of reach of most Cubans, but have offered a solution for a growing class of private business owners and those who still receive money from relatives abroad. The government, aiming to encourage such investments, late on Thursday announced new measures that would waive personal taxes for up to eight years for business people who undertake renewable energy projects. DEMAND INCREASING AS FUEL RUNS SHORT Solar panel installer Raydel Cano, who works in homes and private businesses throughout the Cuban capital Havana, told Reuters demand had increased as fuel has run short in the past few weeks, leaving those with gas and diesel-driven generators in the lurch. "Private businesses see themselves obligated to install panels," he said, noting that alternatives to fully renewable power had mostly become obsolete as the grid falters. Though installing solar panels demands a higher cost upfront, Havana cafe manager Dariem Soto-Navarro said with diesel increasingly difficult to buy, solar was the better option. "In addition to being clean, green energy, it optimises operating costs," he said. "It is without a doubt one of the best solutions for entrepreneurs and private businesses." Alejandro Arritola, who drives a tricycle-taxi with solar panels installed on the roof, told Reuters he had installed the panels to help him travel further when he runs out of gas. "It extends my range and I don't have to use any gasoline," he said, noting that his family continues to get around with ease despite the shortages. "If there's no public transportation, it doesn't matter." The Trump administration says its measures increase pressure for political change in Cuba. On Wednesday, White House press secretary Karoline Leavitt said it was in Cuba's "best interest to make very dramatic changes very soon." The U.N. has warned that if Cuba's energy needs are not met this could cause a humanitarian crisis. The island, already suffering from severe shortages of food, fuel and medicine, has implemented rationing measures to protect essential services. Russia, one of Cuba's last remaining oil suppliers, is preparing to send crude in the near future, Izvestia newspaper reported last week, without providing a specific date. REUTERS Cuba E-paper Newsletters Podcasts RSS Feed About Us Terms & Conditions Privacy Policy Need help? Reach us here. Advertise with us
It’s not hard to find a Connecticut church that dates back to the 19th or even the 18th century. But finding a way to heat and cool these old buildings as utility costs rise and congregations shrink is a timely challenge. Rev. Albert Bailey is the pastor at Shiloh Baptist Church, one of Hartford’s oldest Black churches, which dates back to the early 1900s. The church can seat up to 500 people, but a good turnout nowadays is about 100 people. Still, the place needs to be heated and cooled, even if fewer people are turning up. “This space is huge,” Bailey said. “It takes a lot to light it up. It takes a lot to heat it up.” In order to keep the bills down, the church reduced its number of open days. It also holds most of its meetings and choir rehearsals during the day to save money and avoid keeping the lights on at night. But that only keeps costs down so much. Helping houses of worship go green “Energy efficiency is really the critical step,” said Terri Eickel, executive director of the Interreligious Eco-Justice Network, a faith-based environmental group. Eickel and the group work with houses of worship across Connecticut, giving talks and workshops on energy efficiency and awarding small grants to help houses of worship offset the costs of installing heat pumps, solar panels and battery storage. “I have one congregation in Greenwich looking at geothermal,” Eickel said. So far, Eickel and her group have helped 250 houses of worship go green. Connecticut’s older churches have some of the trickiest issues to deal with, she said. “They literally have no insulation,” Eickel said. “They can have issues with mold. Sometimes they have water rising up through the basement floors and stuff like that. They’ve got multiple issues to deal with and especially as climate change has made things worse.” But boosting energy efficiency is not just about saving costs, it’s also about faith. “Every faith tradition talks about the importance of caring for the planet. Faith traditions talk about not wasting,” Eickel said. Eickel’s group awarded Shiloh Baptist Church a small grant that helped them put energy-efficient lights in its auditorium where it serves meals to people in need. Pastor Bailey said the new lights lower their bills by about $90 a month, which goes back to the soup kitchen and food pantry when donations run low. “It really helps us out,” Bailey said. “If you take that $90 times 12, it’s a nice little considerable chunk for us.” A legacy for future worshippers Eickel’s group also awarded energy efficiency and solar grants to Temple Bnai Israel, a synagogue in Willimantic where the furnace has been on the brink, leaving worshippers upstairs feeling way too cold or boiling hot. “The furnace would — as one of our maintenance guys said — it would just decide when it wanted to go on, decide when it wanted to go off. It was completely random,” Rabbi Jeremy Schwartz said. Now, the synagogue is swapping the furnace for heat pumps and adding solar panels, which is expected to lower operating costs by $20,000. Back in October, worshippers at the synagogue took part in a Sun Day rally to promote the benefits of solar energy. People chanted on the sidewalk with signs as cars passed and honked. “I love solar,” said 8-year-old Charlotte Wilkinson into the megaphone. It’s this younger generation that Schwartz said they’re doing this work for. “The Earth is a holy gift, an incredibly beautiful one,” he said, “so to sustain it is one of our values.” Áine Pennello is a Report for America corps member, covering the environment and climate change for Connecticut Public Copyright 2026 Connecticut Public Radio You are leaving gbh.org and going to a web page that is not owned by GBH. If you are streaming, your experience will be interrupted.
Panasonic has launched a new home fuel cell system for detached houses, designed to boost solar self-consumption through HEMS‑based smart scheduling. The unit generates electricity and heat from gas, supports demand response, and can supply emergency power during outages. The Ene-Farm system Image: Panasonic Japanese industrial group Panasonic has unveiled a new fuel cell cogeneration system under its long-running Ene‑farm brand, aimed at detached homes and designed to increase on-site solar self-consumption. The system integrates with a home energy management system (HEMS) capable of forecasting surplus electricity from solar PV or the grid. Based on these forecasts, the HEMS schedules fuel cell operation to coincide with periods when solar panels produce more electricity than the household requires, maximizing self-consumption. The unit also supports Echonet Lite, a Japanese smart-device standard, enabling participation in demand response (DR) programs. When the system receives a power-reduction order, Ene‑farm pauses electricity generation, allowing more power to flow from the grid and increasing household consumption. Conversely, a power-generation request triggers electricity production, reducing the amount of grid power needed and easing supply constraints. The system operates using either methane or liquefied petroleum gas (LPG). Inside the unit, a fuel processor extracts hydrogen from the methane contained in the supplied gas, and this hydrogen is then fed into the fuel cell stack to generate electricity through an electrochemical reaction. The system delivers a power generation output of 200–700 W for the city gas model and 300–700 W for the LPG model. It achieves a rated electrical efficiency of 41.0% for lower heating value (LHV) or 37.0% for higher heating value (HHV) with methane, and 40.0% (LHV) or 36.8% (HHV) with LP gas. In addition to producing electricity, the system captures the heat generated during the reaction process and reuses it to heat water stored in an approximately 100-liter tank for household applications such as showers, taps, and space heating. The rated heat recovery efficiency reaches 57.0% for LHV or 51.5% for HHV for methane, and 61.0% for LHV or 56.2% for HHV for LPG. Thanks to this combined production of electricity and useful heat, the overall efficiency rises to 98.0% for LHV or 88.5% for HHV with methane, and up to 101.0% for LHV or 93.0% for HHV with LPG. When hot water demand exceeds the heat available from the fuel cell, a backup boiler or auxiliary heat source automatically supplements the system to ensure a stable and continuous supply. During power outages, the unit can also provide emergency electricity with a maximum AC output of 500 W. The fuel cell unit measures 1,650 mm x 400 mm x 350 mm, while the hot water storage unit has a size of 1,650 mm x 790 mm x 350 mm. The dry weight is 59 kg for the fuel cell unit and 73 kg for the hot water storage unit. The product will be available for sale in Japan from April 1. In September, Panasonic began testing a new energy management system (EMS) that helps increase residential PV self-consumption by combining solar energy generation with heat pumps and batteries. Recently, it also released a new version of its Eco Cute CO2 heat pump that is equipped with a solar radiation shift function adjusting domestic hot water (DHW) production during daytime to rooftop PV power generation. Last year, it also integrated a series of home energy management solutions into its Aquarea air-to-water heat pumps for commercial and multi-dwelling residential applications. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. More articles from Emiliano Bellini Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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Published 5:35 am Friday, February 20, 2026 By Michael Kohn The Confederated Tribes of Warm Springs are reviewing proposals for large-scale solar energy developments that could span thousands of acres on the Warm Springs Reservation, including land once considered for a racetrack. Austin Smith Jr., general manager of the tribe’s natural resources branch, said multiple developers have approached the tribe about building solar facilities on reservation parcels. Smith also chairs the tribe’s resource identification team, which evaluates projects under its Integrated Resource Management Plan. Expanding solar production on the reservation could provide a new source of long-term revenue for the tribes while also contributing carbon-free electricity to the regional grid, helping Oregon meet its climate goals and greenhouse gas reduction targets. Yet solar projects have other environmental concerns, ranging from viewshed changes to industrial development. One project currently under review would cover about 2,200 acres. The proposal is in a 30-day evaluation period, during which tribal environmental staff are assessing soil conditions, available sunlight and potential impacts to grazing lands, agriculture and traditional food-gathering areas. “It’s being evaluated if it’s feasible based off of the soil conditions, the amount of sunshine in these areas, damage and mitigation opportunities to livestock grazing, to agriculture, to first foods in the area,” Smith said. A separate developer has conducted a preliminary geographic information system analysis for a larger solar installation that could range from 8,000 to 10,000 acres. That project has not yet undergone a full site evaluation. The larger proposal is partly driven by access to major transmission infrastructure, including lines operated by the Bonneville Power Administration and Portland General Electric that cross the reservation. Interconnection to high-voltage lines is a key factor in determining whether utility-scale solar projects are financially feasible. The tribe has been exploring multiple avenues for developing solar energy. In early 2025, it was awarded $248,000 in federal funding for solar projects on reservation land to pay for geotechnical engineering services required to advance development. In 2024, the tribes also announced they were in talks with Florida-based BrightNight to build a 250-megawatt solar farm on the reservation. If built, the project would be among the largest in Oregon. One potential solar location under consideration includes land previously proposed as the site of a car racetrack more than a decade ago. The racetrack plan was rejected after concerns that it would cause excessive damage to rangeland. The area, located on open flats near Mill Creek off Highway 26, is now being evaluated as a possible site for solar development. Smith said environmental services staff and resource managers are continuing to study the proposals to determine whether they align with the tribe’s long-term land management priorities. No final decisions have been made. Michael Kohn has been public lands and environment reporter with The Bulletin since 2019. He enjoys hiking in the hills and forests near Bend with his family and exploring the state of Oregon. He can be reached at: 541-617-7818, michael.kohn@bendbulletin.com
In a new weekly update for pv magazine, OPIS, a Dow Jones company, provides a quick look at the main price trends in the global PV industry. Image: OPIS Wafer prices continued to trend downward, marking the fourth consecutive week of declines and highlighting manufacturers’ increasing reliance on price concessions to stimulate sales and ease mounting inventory and cash flow pressures, according to market participants. Free-On-Board (FOB) China prices for n-type M10 and n-type G12 wafers declined week on week by 2.38% and 4.98%, to $0.164/pc and $0.191/pc, respectively, according to the OPIS Global Solar Markets Report released on February 16. The broader wafer market environment remains subdued and largely passive, characterized by weak trading activity and ongoing inventory accumulation, according to market sources. The photovoltaic installation market’s seasonal slowdown has directly weakened downstream demand for upstream production materials, while elevated manufacturing costs at the downstream level have further constrained buyers’ ability to absorb current wafer prices. According to industry feedback last week, operating rates at major wafer producers have fallen below 50%. Even specialized wafer manufacturers, which traditionally maintained utilization rates of up to 80%, have seen operating rates decline to below 70%. A market observer noted that the broad-based reduction in operating rates suggests prices have fallen to levels that are no longer economically sustainable for manufacturers. Nevertheless, some market participants indicated that downstream operating rates are likely to recover after the Lunar New Year, as certain cell and module producers still have outstanding orders to fulfill. This could lead to a modest rebound in post-holiday wafer procurement volumes. However, a trading source cautioned that the potential impact on prices may be limited, given that current wafer inventories are estimated at approximately 25 GW. Financial pressure on wafer manufacturers remains significant. This is highlighted by the January 2026 edition of the mainstream photovoltaic product cost analysis recently released by the China Photovoltaic Industry Association. The assessment estimated the tax-inclusive full production cost of n-type G12R wafers at CNY 1.945 ($0.28)/pc in January 2026. In contrast, according to industry sources, the prevailing domestic transaction price for this wafer specification in China currently stands at approximately CNY 1.2–1.3/pc, indicating substantial margin compression. A market participant noted that while the pricing reference of the China Photovoltaic Industry Association (CPIA) functions more as guidance than as a binding standard, it may nonetheless influence market sentiment. In particular, it could provide psychological price support, potentially helping to slow the pace of declines and contribute to short-term stabilization. OPIS, a Dow Jones company, provides energy prices, news, data, and analysis on gasoline, diesel, jet fuel, LPG/NGL, coal, metals, and chemicals, as well as renewable fuels and environmental commodities. It acquired pricing data assets from Singapore Solar Exchange in 2022 and now publishes the OPIS APAC Solar Weekly Report. The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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Indian state-owned power producer NTPC, a NTPC Green Energy subsidiary, has commissioned 165MW of solar capacity at its 1.25GW Khavda-II solar project in Gujarat, advancing the build-out of one of the country’s largest renewable energy hubs. The Khavda site, also called Gujarat Hybrid Renewable Energy Park, is set to ultimately comprise 30GW of solar PV and wind capacity in seven phases. The second phase will host close to 5GW of solar capacity, with 130MW of Khavda-I having entered commercial operation in January. NTPC is also planning to install a 100MWh vanadium redox flow battery system at the park to provide long-duration energy storage. Get Premium Subscription Announced by the Government of India in 2020, the Khavda project spans 60,000 hectares and is set to deliver 30GW of solar alongside wind capacity. Reports vary on the planned completion date, with estimates set between late 2026 and 2030. At the time of the announcement, the transmission system for the first 15GW was supposed to be implemented in three phases. The remaining 15GW will be evacuated in phases: Phase IV (Jun 2025-Jun 2026) – 7 GW via High Voltage Alternating Current (HVAC); Phase V (Dec 2026-Mar 2027) – 4 GW via High Voltage Direct Current (HVDC); Phase VI (beyond Mar 2027) – 4 GW via upgraded HVDC with 765 kV interconnections as needed. This phased rollout ensures the park’s full 30 GW capacity can be efficiently integrated into India’s grid. In September 2024, renewable energy company Adani Green Energy signed a 5GW, 25-year power purchase agreement (PPA) with Maharashtra’s MSEDCL. The power will come from the 30GW Khavda solar park, with projects set to be developed over the next three years and linked to the Interstate Transmission System. Indian solar module maker Vikram Solar signed a 326.6MW supply deal with Gujarat State Electricity Corporation in September last year. This raised Vikram’s total contribution to the Khavda park above 700MW, following its 393.9MW tunnel oxide passivated contact (TOPCon) module supply in June 2024. In August 2025, NGEL commissioned 212.5MW of solar capacity at its 1.25GW Khavda-I solar project. The current commercial capacity of NGEL stands at 8.82GW. With the addition of this capacity, the total installed capacity of the NGEL has increased to 8.99GW.
Solar Power World By Kelly Pickerel | India’s GREW Solar will launch its next-generation ALL BLACK series, G2G M10 TOPCon Series and G2G G12R TOPCon High-Power Series at RE+ 2025. Designed for residential applications, the sleek ALL BLACK Series comes with a 25-year warranty. For utility-scale, commercial, and industrial applications, GREW Solar offers G2G M10 TOPCon Series that delivers up to 590 W. The G2G G12R TOPCon High-Power Series reaches up to 635 W. Both the G2G M10 and G2G G12R series come with 30-year performance warranties. GREW Solar’s vertically integrated, India-based 11-GW module manufacturing is fully UFLPA-compliant. With in-house IEC testing, including 25+ protocols such as hail impact and mechanical load testing, the company ensures consistent, bankable quality. With its upcoming 8.-GW PV cell facility in India, GREW Solar takes a significant step toward making India a global hub for advanced solar manufacturing. GREW Solar’s sustainability commitments include solar-powered production, wastewater recycling, and working closely with vendors encouraging them to use reusable pallets wherever possible. “This launch marks our most significant step yet into the North American market,” said Vinay Thadani, CEO & Director, GREW Solar. “By combining Tier 1 efficiency with compliance assurance and BOS cost savings, we are delivering exactly what global developers need in today’s challenging project environment.” News item from GREW 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.
As part of the ongoing Anker SOLIX Power Deals, the brand has launched a 72-hour weekend flash sale that is cutting up to 56% off the tags on several power station bundles. Starting from the lowest-priced offer, you can pick up Anker’s SOLIX C1000 Gen 2 Portable Power Station with a 200W solar panel and a free water bottle at $649.99 shipped, beating out its Amazon pricing by $90. The bundle carries a $1,598 MSRP direct from Anker, however, it’s been readily available at Amazon keeping between $812 and $730 in 2026. While we did see it go lower in 2025, you’re still looking at a solid $162 markdown off the going rate ($948 off the MSRP) that gives you the best price we have tracked since Christmas sales ended. Head below to check out the other flash offers on bundles for the C1000 Gen 1, C2000 Gen 2, F3000, and F3800 Plus power stations. Starts at a 12,288Wh LiFePO4 capacity that can expand up to 180kWh, 12,000W output power – plus at an exclusive new $6,499 low The Anker SOLIX C1000 Gen 2 power station, as the name implies, is the second-generation upgraded model that brings along a 1,024Wh LiFePO4 battery capacity in a much smaller and lighter form factor, one which I highlighted in my hands-on tested review. Despite its smaller size, it still packs quite the punch with its 10 output ports (5x AC, 2x 140W USB-C, 1x 15W USB-C, 1x 12W USB-A, and a 120W car port) providing up to 2,000W of steady power that can surge up to a 3,000W maximum. The bundle here starts you with 200W of solar input towards its maximum 600W limit, with other recharging options being the faster AC charging, using the passthrough charging feature with a gas generator, utilizing both AC and solar together, or by plugging into your car’s auxiliary port (or upgrading to an alternator charger for faster charging on-the-go). You can shop all these flash sales and the full lineup of power deals on the main landing page here, while other deals/sales from alternate brands can be found waiting for you in our dedicated power stations hub here. FTC: We use income earning auto affiliate links.More. Starts at a 12,288Wh LiFePO4 capacity that can expand up to 180kWh, 12,000W output power – plus at an exclusive new $6,499 low Subscribe to the 9to5Toys YouTube Channel for all of the latest videos, reviews, and more!
Legacy solar models focused on daytime production, but the shift to battery-driven self-consumption is creating a performance gap that puts long-term ROI at risk. Image: Pexels, Los Muertos Crew From pv magazine USA For most of solar’s modern history, system performance modeling followed a simple rule: when the sun is shining, solar produces. Inverters operated near their optimal power range, exported excess energy to the grid, and financial projections assumed relatively straightforward conversion losses. That paradigm no longer holds. As residential solar markets rapidly transition to solar-plus-storage—driven by utilities increasingly penalizing exports—systems are being operated in fundamentally different ways. Yet many financial models, underwriting assumptions, and performance guarantees still reflect a 1:1 net-energy metering and a PV only world. The result is a growing mismatch between modeled performance and real-world outcomes, with meaningful implications for long-term return on investment (ROI). Self-consumption optimization Historically, net metering tariffs rewarded production regardless of timing, and inverter efficiency curves were designed around daytime, mid-power operation. Solar value was maximized by exporting energy and avoiding the expense of storage. Energy flowed directly from panels to the grid or home loads, and systems rarely spent significant time operating at very low output levels. Today’s economics are inverted. In states like California, Hawaii, Arizona, Nevada, and New York—and increasingly across much of the U.S.—exported energy is worth far less than energy purchased from the utility. In some markets, exports are credited at wholesale rates that can be two to three times lower than retail electricity prices. As a result, batteries are no longer a “nice to have” backup feature; they are an economic necessity configured to maximize the self-consumption of solar energy. This shift changes not only where energy flows, but how equipment operates. Instead of pushing energy out quickly, systems now prioritize keeping energy on site. Batteries charge to avoid solar export, discharge slowly over long periods, and are likely to cycle more frequently. Inverters spend far more time operating at low power levels under self-consumption-focused solar-plus-storage operation–conditions that were once rare but are now common.
Legacy models National laboratory research, including work from the National Renewable Energy Laboratory, has begun to explore how behind-the-meter storage and self-consumption strategies alter system operating profiles. However, much of the industry’s widely used production and financial modeling infrastructure and methodologies still reflect assumptions developed for PV-only or export-optimized systems (e.g. time-of-use operation), rather than the extended low-power and high-throughput operation now common in storage-heavy designs where self-consumption delivers the highest value. These operating conditions expose different efficiency weaknesses depending on system architecture, rather than a single universal loss mechanism. In reality, modern solar-plus-storage systems experience compounded losses across multiple steps: Individually, some losses may appear marginal, but in many system architectures at least one dominant loss mechanism is not. Different designs shift inefficiencies to different parts of the system—such as AC-coupling losses, low-power inverter inefficiency, or high self-consumption overhead—making it difficult for any single architecture to maintain high efficiency across all operating modes. Collectively, these losses can materially reduce annual energy delivered at the customer meter. What has become increasingly clear is that not all inverter and storage designs behave the same way under prolonged low-power operation — and differences that appear negligible at nameplate ratings can become material when systems spend most of their lives operating well below peak output. Efficiency curves that look similar at nameplate ratings can diverge meaningfully when systems spend most of their operating life charging, discharging, or idling at a fraction of rated output — precisely the conditions created by prioritizing self-consumption. In these conditions, some systems retain efficiency far better than others. [slide 3) Figure 3: System efficiency curves under varying power levels. DC-coupled architectures with optimizers maintain higher efficiency during the extended low-power operation typical of self-consumption strategies. Importantly, this does not mean all solar-plus-storage systems are destined to underperform. Some technologies and architectures are better suited to sustained low-power, self-consumption-heavy operation than others. As a result, asset owners, installers, and financiers should scrutinize not just peak specifications, but how different system designs perform across real-world operating conditions. For tax equity, cash equity, and especially debt investors, this issue is not academic. Many residential portfolios rely on long-term production estimates to support performance guarantees, debt service coverage ratios, and investor returns. If a system is modeled using legacy assumptions but operated under modern self-consumption strategies, the asset may systematically underperform projections, even if all equipment functions as specified. This is particularly concerning in an industry where margins are already thin. Performance guarantees paid to homeowners or commercial off-takers come directly out of operating cash flow. Underperformance increases operational risk, weakens portfolio economics, and can ripple through the capital stack. Importantly, this risk does not depend solely on what equipment is installed—but on how it is used. As self-consumption-heavy operation becomes more common, some TPO asset owners may have unseen impacts of efficiency losses. Gaps between modeled and delivered energy may only amount to a few percentage points annually, but those gaps compound meaningfully over a 25- to 35-year asset life. Even modest deviations can translate into significant financial exposure when applied across large portfolios or long-term performance guarantees with large concentrations of assets in export penalized markets. Customer perspective Recent industry reporting underscores this shift. While backup power remains an important selling point, homeowners increasingly cite bill savings and energy self-supply as their primary motivations for installing batteries. In unfavorable export markets, published market analyses show storage attachment rates exceeding 75%, driven largely by economics rather than resilience. This means systems are intentionally being operated in ways that legacy models never anticipated. Batteries are stretched across long discharge windows throughout the night instead of discharging their energy in a few peak hours in the evening under TOU tariffs. Exports are now avoided whenever possible. Equipment is optimized for economics, not nameplate performance. In a market that relies heavily on referrals and peer validation, underdelivering on promised bill savings has downstream consequences. Unhappy customers not only dampen referral-driven growth, but can also increase payment defaults, directly impacting portfolio performance for TPO providers and financiers. Solar has faced similar moments before. A decade ago, financiers scrutinized module degradation rates down to a few tenths of a percent, recognizing how small annual differences could materially impact lifetime returns and valuations. Today’s challenge is analogous. The efficiency impacts of self-consumption-heavy operation may exceed the financial importance of degradation assumptions. Energy models typically are focused on estimating solar generation and do not typically consider the delivery path in this operating mode. As more markets and regions transition to unfavorable export tariffs, storage and self-consumption are essential strategies for solar’s continued growth in markets with high renewable penetration (a driver for unfavorable export tariffs). Stakeholders across the value chain should consider updating their assumptions: In response, several technology providers have begun publishing technical guidance intended to help financiers and developers better quantify energy flows and efficiency impacts in storage-heavy operating modes. Accurately accounting for energy flows before and after storage, including excess conversion losses introduced by system architecture, as well as system efficiency during extended low-power operation, is increasingly essential for understanding true system value in self-consumption-driven markets. Ignoring these shifts risks a future where assets consistently underperform expectations, not because the hardware failed, but because the modeling methodologies didn’t keep pace with the market. As solar-plus-storage becomes the default rather than the exception, success will depend less on installed capacity and more on accurately accounting for how energy actually flows. The era of “suns out, guns out” is over. The era of self-consumption economics has arrived, and the industry’s models need to reflect it. Author Bio: Sean McPherson, founder of Full Stack Energy Advisors, is a renewable energy veteran with over 20 years of technical and commercial experience, largely focused on distributed generation. He has led technical diligence for over $7 billion in structured finance across residential, commercial, and utility-scale projects. His expertise spans the product lifecycle, from hardware evaluation, energy modeling, system design, and construction to asset management and performance analytics for distributed portfolios of up to 650,000 assets. Sean is a UC San Diego Mechanical Engineering graduate and former NABCEP-certified professional, Full Stack Energy Advisors specializes in technical risk management, portfolio asset management, product strategy, and hardware evaluation..
The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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He clarified that the bank mostly works with investors and businessmen as it has a limited number of branches.
ERBIL, Kurdistan Region of Iraq – The state-owned Trade Bank of Iraq (TBI) on Friday announced it will provide loans under a solar energy initiative to employees whose salaries are deposited with the bank.
The move is part of a broader effort to boost alternative energy and reduce the strain on the country’s power grid, the bank’s head of the board of directors Bilal al-Hamdani told state media.
“The bank granted solar energy initiative loans to employees whose salaries are nationalized, as part of its approach to supporting alternative energy projects and reducing pressure on the electrical system,” Hamdani said.
He clarified that the bank mostly works with investors and businessmen as it has a limited number of branches.
The national grid in Iraq routinely shuts off for hours a day, excluding the Kurdistan Region, where a landmark round-the-clock electricity project has vastly improved the provision of electricity. Iraq plans to generate 12,000 megawatts from renewable sources by 2030, aiming to ease pressure on the national grid. On peak summer days, demand may reach 55,000 megawatts while supply remains around 28 megawatts, showing the urgent need for new solutions. Many Iraqis are turning to solar energy to cope with frequent and costly power outages. In areas like Mosul and agricultural regions, solar panels on homes and farms are helping people power their irrigation systems and reduce electricity bills.
The India solar rooftop market attained a volume of 13.70 Gigawatt in 2024. The market is expected to grow at a CAGR of 28.40% during the forecast period of 2025-2034 to reach a volume of 166.87 Gigawatt by 2034. Urban EV charging hubs powered by rooftop solar systems are primarily driving demand by combining clean mobility with decentralised energy generation.
The market is undergoing a structural shift, driven by the commercialisation of distributed energy and evolving electricity economics. One major driving factor is the surge in time-of-day (ToD) tariff regimes and corporate decarbonisation mandates. With the Central Electricity Regulatory Commission pushing for ToD metering in 2024 and mandating its rollout in 2025, commercial users, especially in IT hubs and industrial clusters, are fast-tracking rooftop solar adoption to hedge against peak hour charges. As per the India solar rooftop market analysis, the country’s capacity is expected to reach 25-30 GW by FY27, led by the commercial and industrial (C&I) sector, which made up 75% of installations.
Government-backed incentives are also amplifying this momentum. The PM Surya Ghar Muft Bijli Yojana, launched in December 2024, targeting 1 crore households, has achieved 10 lakh application conversion within the first quarter of 2025. Moreover, the Rooftop Solar Programme Phase II, extended till 2026, is funding for infrastructure, directly supporting discom-tied projects in both urban and peri-urban zones.
Moreover, India’s net metering cap for residential systems is prompting residential users with larger rooftops (especially in tier-1 and tier-2 cities) to participate actively in decentralised generation. Together, policy traction, tariff rationalisation, and private sector PPA models are shaping the India solar rooftop market dynamics that is moving beyond its subsidy-first identity.
Surge in Corporate Renewable Procurement & Green Building Mandates
The India solar rooftop market is being rapidly reshaped by corporate buyers. Leading real estate developers such as DLF and Embassy are now embedding rooftop solar in all Grade A commercial properties, responding to updated GRIHA and IGBC certification benchmarks. For example, TATA Power’s cumulative installed rooftop solar capacity was 343 MW as of June 2024. It had over 300 projects and more than 200 clients in India 2024. Additionally, multinational companies such as Infosys and Amazon India have committed to 100% RE usage across operations, with rooftop solutions forming a vital part of their decentralised energy sector.
Adoption of Building-Integrated Photovoltaics (BIPV)
A growing trend in the India solar rooftop market is the use of Building-Integrated Photovoltaics (BIPV), where solar panels are seamlessly built into architectural elements like facades, skylights, and windows. Such innovations have been driven by government incentives and encouragement. For example, in June 2025, through its Renewable Energy Research and Technology Development (RE-RTD) Program, the Ministry of New and Renewable Energy (MNRE) has introduced a brand-new “Innovation Challenge for Circularity in Renewable Energy Technologies – Batteries and Solar Photovoltaic.” This approach not only generates clean energy but also enhances building aesthetics and thermal efficiency. Companies like Waaree and Jakson have begun offering BIPV solutions tailored for commercial spaces and green-certified buildings. BIPV is especially gaining traction in high-density cities like Mumbai and Bengaluru, where rooftop space is limited.
Hybridisation of Rooftop Solar with Storage and EV Infrastructure
With India’s EV push going mainstream, the market is witnessing more hybridised use cases. Start-ups like Oorjan and Sun Mobility are also pioneering battery-solar combos for gated communities. This convergence is not just enhancing grid resilience but also opening up new India solar rooftop market opportunities in urban mobility and micro-energy hubs, especially in Tier-1 and Tier-2 cities. Real estate developers are now integrating rooftop-EV combos into project blueprints, while state EV policies are incentivising co-located solar charging infrastructure.
Discom-Led Virtual Net Metering and Peer-to-Peer Models
Virtual net metering (VNM) has also picked up momentum. Platforms like Power Ledger and SunExchange are also entering India’s peer-to-peer rooftop energy trading space, with trials initiated in Uttar Pradesh and Karnataka. These new business models, supported by blockchain technology are enabling tenants, SMEs and rental spaces to indirectly participate in solar ownership, which was earlier a major India solar rooftop market hurdle.
Digital Twin and AI Integration in Rooftop Solar Planning
The integration of digital twin and AI models is redefining solar project design and performance forecasting. For example, ReNew Power offers an AI-based platform that simulates rooftop yield under varying pollution and angle conditions, reducing project planning time to a significant extent. On the other hand, L&T-SuFin is offering real-time yield dashboards to commercial clients via its procurement marketplace. These innovations, while subtle, are improving investor confidence, reducing payback uncertainty and supporting scalable PPA structures, essential for B2B scalability in sectors like textiles, logistics and pharma manufacturing, boosting the India solar rooftop market value.
Competitive Landscape
Leading India solar rooftop market players are shifting focus from hardware to holistic energy solutions. Companies are concentrating on integrating smart metering, digital monitoring tools, and battery hybrid systems to enhance value delivery. As state policies favour EV-charging integration and peer-to-peer solar trading, new growth opportunities are emerging for digital solar service providers.
Emerging India solar rooftop companies are collaborating to offer rooftop-as-a-service models, which reduce capex barriers for MSMEs and residential buyers. With rising ESG scrutiny, firms offering data-backed carbon tracking and audit-ready solar dashboards are gaining preference among corporates. Innovative financing options such as subscription solar and group net metering are also opening opportunities in underserved markets. Companies that diversify regionally and bundle ancillary services like storage and maintenance contracts are most likely to stay ahead.
Avaada Group
Avaada Group, established in 2017 and headquartered in Mumbai, focuses on rooftop solar for industrial and institutional clients. The company offers turnkey EPC solutions and has introduced green hydrogen-linked rooftop projects for sustainable campuses.
Waaree Energies Ltd
Waaree Energies Ltd., founded in 1989, manufactures high-efficiency solar panels and provides integrated rooftop solutions. It caters to both residential and C&I clients, with a growing focus on BIPV systems and digital energy management tools.
Tata Power Renewable Energy Limited
Tata Power Renewable Energy Limited, set up in 2007 and headquartered in Mumbai, delivers rooftop solar solutions across residential, commercial, and institutional segments. The firm emphasises digital platforms, smart metering, and project financing under government subsidy schemes.
Adani Group
Adani Group, through Adani Solar, established in 2015 and based in Ahmedabad, offers rooftop systems with vertically integrated panel production. It focuses on high-capacity industrial installations and recently expanded into community solar and peer-to-peer trading pilot projects.
Other key players in the market are Goldi Solar Pvt Ltd., Premier Energies, Mahindra Group, Vikram Solar Ltd., ENPEE Group, and Gensol Group, among others. Key Highlights of the India Solar Rooftop Market Report: Key Market Trends and Insights: Market Size & Forecast: Key Attributes:
Key Topics Covered:
1 Executive Summary 1.1 Market Size 2024-2025 1.2 Market Growth 2025(F)-2034(F) 1.3 Key Demand Drivers 1.4 Key Players and Competitive Structure 1.5 Industry Best Practices 1.6 Recent Trends and Developments 1.7 Industry Outlook
2 Market Overview and Stakeholder Insights 2.1 Market Trends 2.2 Key Verticals 2.3 Key Regions 2.4 Supplier Power 2.5 Buyer Power 2.6 Key Market Opportunities and Risks 2.7 Key Initiatives by Stakeholders
3 Economic Summary 3.1 GDP Outlook 3.2 GDP Per Capita Growth 3.3 Inflation Trends 3.4 Democracy Index 3.5 Gross Public Debt Ratios 3.6 Balance of Payment (BoP) Position 3.7 Population Outlook 3.8 Urbanisation Trends
4 Country Risk Profiles 4.1 Country Risk 4.2 Business Climate
5 Asia Pacific Solar Rooftop Market Analysis 5.1 Key Industry Highlights 5.2 Asia Pacific Solar Rooftop Historical Market (2018-2024) 5.3 Asia Pacific Solar Rooftop Market Forecast (2025-2034)
6 India Solar Rooftop Market Analysis 6.1 Key Industry Highlights 6.2 India Solar Rooftop Historical Market (2018-2024) 6.3 India Solar Rooftop Market Forecast (2025-2034) 6.4 India Solar Rooftop Market by End User 6.4.1 Industrial 6.4.2 Commercial 6.4.3 Residential 6.5 India Solar Rooftop Market by Grid Type 6.5.1 On Grid 6.5.2 Off Grid 6.6 India Solar Rooftop Market by Region 6.6.1 North India 6.6.2 South India 6.6.3 East India 6.6.4 West India
7 Market Dynamics 7.1 SWOT Analysis 7.2 Porter’s Five Forces Analysis 7.3 Key Indicators of Demand 7.4 Key Indicators of Price
8 Competitive Landscape 8.1 Supplier Selection 8.2 Key India Players 8.3 Key Regional Players 8.4 Key Player Strategies 8.5 Company Profiles For more information about this report visit https://www.researchandmarkets.com/r/pbaj5 About ResearchAndMarkets.com ResearchAndMarkets.com is the world’s leading source for international market research reports and market data. We provide you with the latest data on international and regional markets, key industries, the top companies, new products and the latest trends. Attachment Dublin, Feb. 20, 2026 (GLOBE NEWSWIRE) — The "Canada Existing & Upcoming Data Center Portfolio" report has been added to ResearchAndMarkets.com's offering. Canada hosts around 117 existing… Dublin, Feb. 20, 2026 (GLOBE NEWSWIRE) — The "U.S. Existing & Upcoming Data Center Portfolio" report has been added to ResearchAndMarkets.com's offering. Over 670+ upcoming colocation and…
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As distributed solar generation gains a larger share of Brazil’s electricity system, challenges such as reverse energy flows, voltage instability, and centralized generation outages are becoming increasingly frequent. Battery energy storage systems (BESS) are often cited as a promising solution, but their effective deployment depends on technical, economic, and regulatory feasibility. In this context, the study “Storage at the Edge: Distributed BESS as a Technical and Regulatory Solution for Brazil’s Energy Transition,” published in Energy Policy, evaluates three BESS implementation strategies in the Brazilian National Interconnected System (SIN) from technical, economic, and regulatory perspectives, based on real operational data from the 12-month period between July 2024 and June 2025: Standalone BESS as independent market agents (Strategy 1);behind-the-meter storage to shift low-voltage consumption (Strategy 2) and co-located BESS with distributed photovoltaic systems to shift PV injection (Strategy 3). Battery operation is modeled using predefined charging and discharging windows designed to reflect viable strategies under current Brazilian market structures and tariffs. Rather than introducing algorithmic innovations, the study’s contribution lies in its empirical foundation and transparency, allowing clear comparisons between strategies and highlighting mismatches between economic incentives, regulatory norms, and system needs.
Strategy 1: Standalone BESS This strategy explores a configuration in which BESS operate as independent market agents participating directly in the wholesale electricity market. Economic results: For a BESS price of BRL 1,250 ($240)/kWh, the return on investment (ROI) is 1.5% when the short-term energy market differential is BRL 400 ($76.60)/MWh. At a BESS price of BRL 500/kWh, a positive ROI of 1.5% is achieved with a spot price differential of BRL 160 /MWh. In the scenario of BRL 500 /kWh and a BRL 400 /MWh differential, ROI could reach 13.4%. The study considers investments viable starting from a minimum ROI of 10–11%. Technical results: While price arbitrage opportunities exist, optimal charge/discharge cycles based on prices do not always align with periods when waste reduction or power variation mitigation is most needed. Up to 72.5 GWh/18.2 GW of BESS could be deployed before excessive load shifting causes nighttime ballast issues. Regulatory perspective: Although technically viable, the strategy currently lacks regulatory support. Brazilian regulations do not recognize storage as a generation/load agent, nor do they allow dispatch or compensation through system services markets.
Strategy 2: Shifting Low-Voltage Consumption This strategy examines BESS installed at low-voltage consumer units, with or without distributed generation, to shift electricity use from nighttime peaks to midday solar surpluses. Batteries are set to charge from 07:00–14:00 and discharge from 17:00–22:00, aligning with peak tariff periods under Brazil’s white tariff system. Economic results: For a BRL 1,500/kWh BESS, ROI is 1.6% with a BRL 320/MWh peak-to-peak tariff difference. For smaller differences (~ BRL80/MWh), ROI becomes positive at BRL 750/kWh or lower. ROI could reach 20% with a 500 BRL/kWh BESS and 400 BRL/MWh tariff difference. Technical results: Batteries with 40 GWh/8.6 GW capacity support temporal alignment between demand and solar generation. Regulatory perspective: Fully permitted, but economic benefits for consumers are modest; under the current tariff, off-peak savings are limited to ~5%.
Strategy 3: Shifting Photovoltaic Injection This strategy uses co-located BESS with distributed PV systems to shift energy injection from surplus periods to high-demand periods. Batteries charge until reaching 3 hours of capacity and discharge from 18:00–21:00 during peak tariffs. Economic results: ROI becomes positive when the peak-to-standard tariff ratio reaches 1.6 with BESS ≤1,000 BRL/kWh. For higher BESS prices, ROI requires ratios ≥1.8. A 500 BRL/kWh BESS with peak tariffs twice standard rates yields ROI up to 16.6%. Weekend simulations show positive ROI in all scenarios. Technical results: Strategy requires 18 GWh/6 GW of BESS. Simple to implement, it benefits from Brazil’s energy compensation scheme: each MWh injected during peak hours converts to ~1.6 MWh of off-peak credit for low-voltage consumers.
Distributed Storage Requires Coordination Incorporating location constraints, real-time dispatch, or coordinated prosumer participation could increase the systemic value of distributed storage, enabling targeted congestion relief and greater flexibility. Achieving this would require more granular data, digital infrastructure, and market access mechanisms currently unavailable in Brazil, making these areas priorities for future research. Ultimately, realizing the potential of distributed storage requires coordinated technical, economic, and regulatory action. As Brazil and other countries transition to more decentralized energy systems, storage will be critical for reliability, efficiency, and equity. Effective implementation also depends on regulatory innovation, market structures, and tariffs that incentivize flexibility. Policymakers should consider creating new functions for storage, enabling load aggregators, and aligning private investment with public interest. From pv magazine Brazil This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. Your email address will not be published.Required fields are marked *
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U.S. researchers are testing regenerative agrivoltaics at a farm in Southern California, combining solar panels with soil-restoring practices like composting, cover cropping, and no-till farming to enhance crop yields, soil health, and water-use efficiency. The pilot evaluates technical, ecological, and economic viability while exploring how this land-sharing approach can optimize food and energy production, reduce irrigation needs, and inform larger-scale deployment and policy frameworks. The Southern California pilot agrivoltaic project Image: Pitzer College Researchers from Pitzer College in the United States have proposed to combine regenerative agriculture with agrivoltaics in an effort to maximize the benefits of both activities. Regenerative agriculture is a farming approach that revitalizes soil, ecosystems, and communities, going beyond merely sustaining production. It actively improves and enriches the land over time through practices like cover cropping, no-till farming, and rotational grazing, which restore soil health and enhance biodiversity. Techniques such as agroforestry, composting, and polycultures further strengthen ecosystems, creating a system that nourishes the soil, supports communities, and produces sustainable food. “Regenerative Agrivoltaics does not necessarily require higher capital expenses than conventional agrivoltaics,” the research lead author, Kevin B. Grell, told pv magazine. “In fact regenerative practices tend to substitute capital input for labor input. In regions where ambient heat reaches a point where the efficiency of the panels are affected, regenerative land management practices may actually contribute with a stronger ambient cooling than conventional practices, thus increasing the PV yield, and in turn lowering the levelized cost of energy (LCOE). “Different regions face different challenges related to the production of food and energy,” co-author Sophie Parker added. “For example, warm and dry regions face challenges related to the irrigation of crops. Rainy regions face challenges related to maximizing the efficiency of electrical production from PV sources given limited sunlight. Locations closer to the poles experience greater seasonal fluctuation in daylength, meaning that crop production is seasonally restricted, and solar panel tilt requires more seasonal adjustment. The deployment of regenerative agriculture could be used to address some of these challenges, but the details of how to modify any particular regenerative agrivoltaic site to address these challenges will be region-specific.”
Want to learn more about the EPC challenges in European agrivoltaics? Join us on March 5 for the Dual harvest, double trouble: Tackling EPC barriers in agrivoltaics design pv magazine session in English language at KEY – The Energy Transition Expo in Rimini. Experts will share insights on current agrivoltaic technologies, key design choices and the main barriers to standardized, scalable dual‑use projects in Europe and Italy, including region‑specific EPC issues. In the Inland Empire of Southern California, The Nature Conservancy and Pitzer College are part of a collaborative group led by the Robert Redford Conservancy that established a regenerative agrivoltaics site at the California Polytechnic University at Pomona’s Spadra Farm. This site’s growing season conditions are hot and dry. “There, we have the ability to study how the regenerative agricultural practice of compost addition, coupled with PV deployment, could enhance soil moisture and potentially reduce the need for irrigation. While the addition of compost alone, or the shading provided by PV alone, can each provide a water-savings benefit, it will be interesting to see what happens when these two practices are combined. In locations where crop growth does not require irrigation, there may be other benefits that come from regenerative agrivoltaics,” Grell stressed. He also explained that no PV configuration is inherently incompatible with regenerative agriculture. “Be it the common fixed-tilt or single-axis tracking, over the horizontally placed ‘fence type’ structures to the canopies used in viticulture, there do not seem to be any constraints due to the regenerative practices. It is more a matter of certain mounting geometries being better suited than others, if the agricultural function involves livestock integration. But that will be the case with conventional solar grazing systems as well.” Grell also emphasized that regenerative agriculture often substitutes biological processes and labor management for chemical and mechanical inputs, thus making regenerative agrivoltaics more labor intensive. “In arid and semi-arid regions such as Southern California, the shade from the panels may provide an added benefit to farm workers, thereby allowing for types of very labor intensive agriculture in areas where heat exposure would otherwise make such farming models impossible,” he also stated. In the study “Regenerative agrivoltaics: Challenges and opportunities in Southern California’s Inland Empire region,” published in Energy Nexus, Grell and his colleagues presented the demonstration site and explored the challenges and opportunities of implementing regenerative agrivoltaics as a land-sharing strategy. The site has six 2.4 m steel columns, each supporting 12 solar modules, arranged for both solar optimization and farm machinery access, with energy stored in a 5.12 kWh mobile battery. The project includes agrivoltaics and control blocks, with sub-plots managed using regenerative and conventional practices in a randomized design. There, the researchers are examining how solar shading combined with regenerative agriculture influences crop yields, soil health, water-use efficiency, and economic viability, with data collected on soil chemistry, microbial life, pollinators, water infiltration, crop production, and energy output. The project evaluates technical, ecological, and economic viability, while informing larger-scale experiments and policy frameworks. Future research should examine real-world economic performance, system design, and scale-dependent effects, including water, soil, and microbial responses. “While large-scale experiments are necessary to reveal hidden or dampened synergistic effects and verify pilot projects’ generalizability, they also have important implications for the social sciences,” the research group concluded. “Determining the economic variability at the agribusiness level involves estimations of upfront investment requirements, on-going fixed and variable costs, as well as revenues generated from the system.”
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India installed 7.8 GW of open-access (off-site C&I) solar in 2025, pushing cumulative capacity past 30 GW by year-end, according to Mercom India. Image: Sunsure From pv magazine India India added 7.8 GW of open-access solar capacity in 2025, a 0.5% increase from 7.7 GW in 2024, according to the “Q4 & Annual 2025 India Solar Open Access Market Report” from Mercom India. Cumulative open-access capacity exceeded 30 GW as of Dec. 31, 2025. “Solar open access demand remains strong, particularly from large industrial users and data centers seeking long-term tariff certainty while meeting sustainability goals,” said Raj Prabhu, CEO of Mercom Capital Group. He added that while rising costs and tighter compliance requirements may affect near-term additions, underlying market drivers remain solid. Karnataka led installations in 2025 with more than 24% of annual additions, followed by Maharashtra at over 20% and Rajasthan at 18%. In the fourth quarter of 2025, India installed 1.6 GW of open-access capacity, down 27% from 2.2 GW in the third quarter and more than 30% lower than the 2.3 GW installed in the fourth quarter of 2024. The report attributed the decline to projects being commissioned earlier in the year ahead of the June expiry of the ISTS charge waiver. Maharashtra, Tamil Nadu, and Gujarat led installations in the fourth quarter, accounting for 27%, 22%, and 17% of additions, respectively. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. More articles from Uma Gupta Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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Under the terms of the deal, Germany’s NexWafe will supply its ultrathin solar wafers to Talon PV’s planned 4.8 GW TOPCon solar cell manufacturing plant in Texas. Initial qualification work will take place at a pilot production line at Fraunhofer ISE’s Photovoltaic Technology Evaluation Center. Talon PV CEO, Adam Tesanovich, and NexWafe VP Business Development USA, Jonathan Pickering Image: NextWafe German solar wafer manufacturer NexWafe has signed a strategic partnership with Texas-based n-type solar cell manufacturer Talon PV. Under the terms of the agreement, NexWafe will supply its EpiNex silicon wafers to support Talon’s TOPCon solar cell manufacturing in the U.S.. The two parties anticipate the partnership represents approximately 7 GW of silicon wafers through to 2032. A statement from the companies adds that they will also collaborate on technical development and qualification efforts to improve TOPCon cell performance using NexWafe’s EpiNex substrates. This work will focus on advanced wafer material quality, ultra-low oxygen content, and next-generation junction engineering approaches to enable higher efficiency and long-term reliability in n-type solar cells. According to details on its website, NexWafe’s EpiNex silicon wafers are manufactured via a direct gas-to-wafer epitaxy process, eliminating both the crystal growth and wire saw processes. Available in thicknesses from 50 μm to 150 μm, the wafers are grown directly to final thickness, which the company says dramatically improves material efficiency and reduces energy consumption. Talon PV announced it is setting up a pilot TOPCon solar cell production line at Fraunhofer ISE’s Photovoltaic Technology Evaluation Center last September, which is where the initial EpiNex wafer qualification work will be conducted. A spokesperson for NexWafe told pv magazine work will begin on making TOPCon cells with EpiNex wafers this year. Talon PV is planning to build a 4.8 GW TOPCon cell manufacturing facility in Baytown, Texas with NexWafe’s EpiNex wafers. The two companies say their partnership aims to “strengthen domestic content in solar products, reduce reliance on imported silicon-based components and advance a resilient Western-aligned supply chain for next-generation photovoltaics.” NexWafe was among eight European companies that received investment in the last round of the European Commission’s Strategic Technologies for Europe Platform Scale Up call. In December 2024, the company achieved a power conversion efficiency of 24.4% for a heterojunction solar cell built with its ultrathin wafers. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. More articles from Patrick Jowett Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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Germany-based solar tracker developer Sunoyster Systems has developed a 440 W lightweight solar panel with a tempered glass cover for low-load commercial and industrial roofs. Image: Holger Laschka, SKF Germany-based solar tracker developer Sunoyster Systems has developed a lightweight tunnel oxide passivated contact (TOPCon) solar panel with a 2 mm tempered glass cover for low-load roofs and facades in the commercial and industrial segment. The Sunoyster G440 is a 440 W solar panel that weighs 12 kg and has 22.2% efficiency. It is based on 108 TOPCon monocrystalline half-cut solar cells and measures 1,756 mm x 1,128 mm x 3.5 mm. It is available with a frame and in a frameless version. The modules are manufactured in China by Sunoyster’s Chinese manufacturing partner, according to the company spokesperson. They are designed to be glued directly to the roof without a traditional substructure or ballasting. With a weight of about 5 kg/m2, they are reportedly suitable for load restricted roof, including roofs finished with sanded bitumen, PVC foil, flexible polyolefin (FPO), Eternit, trapezoidal sheet metal, as well as barrel shaped surfaces, sloped roofs and facades, according to the company. Designed for high voltage systems up to 1,500 V, the modules have a temperature coefficient of -0.29 %/C and an IP68 junction box. Sunoyster Systems was founded in 2011. Its modules were recently installed in a 274 kilowatt project at a German industrial site owned by bearing and seals manufacturer Svenska KullagerFabriken (SKF). Earlier in the year, they were installed in a pilot by Galp Energia in Portugal. In 2022, it also launched a concentrating solar power system for building applications.
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India's corporate solar open access market closed 2025 with a record 7.8 GW of new capacity additions, a slight increase over the 7.7 GW installed in 2024. This achievement, however, was not a smooth upward trend but rather a consequence of developers accelerating project commissioning ahead of the June 2025 expiry of the Inter-State Transmission System (ISTS) charge waiver. This regulatory deadline artificially inflated annual figures, leading to a sharp 29% sequential decline in installations during the fourth quarter, indicating the distortions created by a waiver-driven rush rather than a slowdown in underlying corporate demand. The cumulative installed capacity in this segment now exceeds 30 GW. Despite this quarterly dip, a substantial development pipeline of over 45 GW of solar open access projects under development or in pre-construction signals continued corporate interest, fueled by rising grid tariffs and decarbonisation imperatives. Yet, the evolving regulatory environment, marked by the tapering of the ISTS waiver and volatility in renewable energy certificates, points to a more complex growth trajectory ahead. Karnataka led annual solar open access installations in 2025, contributing over 24% of the total, followed by Maharashtra (20%) and Rajasthan (18%). These states have consistently attracted significant capacity due to supportive policies and substantial industrial demand. However, the fourth quarter saw Maharashtra, Tamil Nadu, and Gujarat account for the bulk of new capacity, reflecting shifting project pipelines. The Green Day-Ahead Market (G-DAM) saw an 18% quarter-on-quarter increase in volumes, with Adani Green Energy accounting for 38% of traded electricity. Conversely, Renewable Energy Certificate (REC) volumes plunged by nearly 58%, and Green Term-Ahead Market (G-TAM) trades declined by 32%, highlighting significant volatility in short-term green energy financial instruments. This trading turbulence suggests a market grappling with price discovery and demand-supply imbalances beyond the immediate project development phase. While Adani Green Energy (AGE) operates with a market capitalization around ₹1.70 trillion and a high P/E ratio of approximately 116x as of February 2026, indicating significant investor expectations for future growth, its stock has notably underperformed the Nifty 50 index.. The company has faced persistent allegations of financial impropriety, including stock manipulation, accounting fraud, bribery schemes, and land acquisition controversies, alongside project-specific issues in India and Sri Lanka.. In contrast, Tata Power, with a market cap around ₹1.21 trillion and a more moderate P/E ratio of roughly 31x, presents a more balanced investment profile.. Tata Power is strategically expanding its renewable capacity, aiming for 25 GW by 2030, and has demonstrated strong performance in rooftop solar installations and hybrid projects.. Forecasts suggest Tata Power's earnings could grow by over 20% annually, a more grounded projection compared to the high expectations placed on AGE.. The broader sector faces structural shifts. The full expiry of the ISTS charge waiver on June 30, 2025, has been replaced by a phased taper, which could increase tariffs by ₹0.40 to ₹1.50 per kWh.. This change, coupled with mandates like the Approved List of Models and Manufacturers (ALMM)-II and challenges in land acquisition and grid connectivity, poses risks to project execution.. However, underlying demand drivers, such as increasing corporate grid tariffs and a strong push for decarbonisation, remain robust. The Union Budget 2026-27 has reinforced support for domestic solar manufacturing and battery storage systems, signalling a commitment to sustainable growth.. The record annual capacity addition is significantly attributable to the regulatory tailwind of the ISTS charge waiver, which effectively lowered delivered renewable power costs by an estimated ₹0.70–0.80 per kWh.. With this waiver now phasing out, projects commissioned after June 2025 face higher transmission costs, potentially impacting project viability and offtake agreements, especially for projects not located near demand centers.. Adani Green Energy's substantial debt-to-equity ratio of approximately 3.7x as of FY2025 and persistent allegations of financial misconduct create significant governance and operational risks.. The company's stock has exhibited volatility and underperformance relative to market indices, raising concerns about its long-term sustainability despite ambitious capacity targets.. Regulatory uncertainty, as seen in Maharashtra with issues like energy banking limits and time-of-day tariffs, also poses challenges for developers.. Furthermore, the mandate to use domestically manufactured solar modules from June 2026 could introduce supply chain complexities and cost pressures.. The significant drop in REC and G-TAM trading volumes underscores a potential disconnect between project development and efficient market mechanisms for green energy, signalling a less stable trading environment than desired. Despite the short-term distortions and emerging risks, the long-term outlook for India's solar open access market remains positive, supported by strong corporate demand for predictable energy costs and sustainability goals.. The substantial development pipeline of over 45 GW indicates continued expansion. Analysts maintain a constructive view on key players like Adani Green Energy, with average target prices suggesting upside potential, though concerns about its high valuation and past controversies persist.. Tata Power is poised for steady growth, backed by its diversified renewable portfolio and a more stable financial footing.. The government's continued policy support through budgets and initiatives like the PM Surya Ghar scheme will likely accelerate adoption.. However, the industry must navigate the transition away from regulatory incentives towards market-driven competitiveness, ensuring robust execution and transparent trading practices to achieve sustainable growth.
In a new weekly update for pv magazine, Solcast, a DNV company, reports that January 2026 saw Europe’s coldest month since 2010, with Eastern Europe and Scandinavia enjoying above-average solar irradiance under stable, dry air, while the UK, Spain, and Portugal faced record cloudiness and rainfall that sharply reduced PV output. Image: Solcast January 2026 delivered Europe’s coldest January since 2010, an exception to warm global temperatures. At the same time record-warm North Atlantic sea-surface temperatures helped create a succession of powerful storm systems. The result was a month of sharp regional contrasts for solar, according to analysis using the Solcast API. Eastern Europe and Scandinavia recorded above-average irradiance under cold, stable air masses, while the UK and parts of Western Europe saw suppressed irradiance due to persistent Atlantic lows. Major PV markets experienced mixed outcomes: Germany ultimately finished the month with favourable irradiance, whereas Spain and Portugal endured one of their gloomiest starts to a year in decades. Across the Iberian Peninsula, Spain and Portugal recorded a distinctly below-average month for solar irradiance. Storm Kristin brought widespread cloud cover and repeated rainfall events, limiting clear-sky windows and reducing daily irradiance totals. January 2026 was the gloomiest on record most many parts of Spain, with nothing close seen since 2016. Rainfall reached 85% above normal, making it the wettest January in 25 years. Portugal saw nationwide rainfall of 233.4 mm, around double the 1991–2020 average of 105 mm, ranking as the country’s second-wettest January since 2000. Ongoing cloud across the month, rather than isolated storm peaks was the dominant feature shaping PV conditions across Iberia. Further north, a series of strong Atlantic low-pressure systems, including Storm Goretti in the UK, tracked repeatedly into northwestern Europe. These systems delivered thick cloud bands, heavy rainfall and strong winds that sharply reduced irradiance across the UK and parts of Europe. Northern Ireland and southern England recorded their wettest January since the 1800s, with flooding and power outages accompanying prolonged overcast conditions. Germany also experienced several storm episodes, with heavy rain and strong winds interrupting solar resource during frontal passages. Clearer, colder air in the wake of these systems from post-frontal cold spells reduced atmospheric moisture and cloud formation, allowing monthly irradiance to finish above the long-term average despite the unsettled pattern. In Scandinavia, the Baltics and Poland, the solar irradiance ran 10% to 50% above average as a severe mid-month cold spell established dry, stable air across Eastern Europe. January 2026 was widely reported as Europe’s coldest January since 2010, bringing travel disruption and localized power outages. While winter day length inherently limits solar availability at these latitudes, reduced atmospheric moisture and more frequent clear or lightly clouded skies produced brighter-than-usual winter days. Far northern latitudes saw very high anomalies in percentage terms, but with limited real benefit to solar generation. Solcast produces these figures by tracking clouds and aerosols at 1-2km resolution globally, using satellite data and proprietary AI/ML algorithms. This data is used to drive irradiance models, enabling Solcast to calculate irradiance at high resolution, with typical bias of less than 2%, and also cloud-tracking forecasts. This data is used by more than 350 companies managing over 300 GW of solar assets globally. The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine. This content is protected by copyright and may not be reused. If you want to cooperate with us and would like to reuse some of our content, please contact: editors@pv-magazine.com. Please be mindful of our community standards. Your email address will not be published.Required fields are marked *
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Author Bio: Sean McPherson, founder of Full Stack Energy Advisors, is a renewable energy veteran with over 20 years of technical and commercial experience, largely focused on distributed generation. He has led technical diligence for over $7 billion in structured finance across residential, commercial, and utility-scale projects. His expertise spans the product lifecycle, from hardware evaluation, energy modeling, system design, and construction to asset management and performance analytics for distributed portfolios of up to 650,000 assets. Sean is a UC San Diego Mechanical Engineering graduate and former NABCEP-certified professional, Full Stack Energy Advisors specializes in technical risk management, portfolio asset management, product strategy, and hardware evaluation.. 
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